Other Income and Expenses [Abstract]

Equity

On May 31, 2017, our board of directors approved an additional $3.0 billion share repurchase authorization. This authorization is in addition to its previous authorization, both of which have no expiration date.

As of September 30, 2017, we had $3.94 billion of remaining share repurchase authorization from our board of directors. We may utilize various methods to effect the repurchases, which could include open market repurchases, negotiated block transactions, accelerated share repurchases or open market solicitations for shares, some of which may be affected through Rule 10b5-1 plans. The timing and amount of future repurchases, if any, will depend upon several factors, including market and business conditions, and such repurchases may be discontinued at any time.

Total share repurchases were as follows for the three and nine months ended September 30, 2017 and 2016:



	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions, except per share data)	2017		2016		2017		2016
Number of shares repurchased	8		1		31		4
Cash paid for shares repurchased	$	452	$	51	$	1,622	$	177
Effective average cost per delivered share	$	53.85	$	42.76	$	52.16	$	41.14

As of September 30, 2017, we had agreements to acquire 985,400 common shares for $55 million, which were settled in early October 2017.

Segment Information

9 Months Ended

Sep. 30, 2017

Segment Reporting [Abstract]

Segment Information

In the first quarter of 2017, we revised our segment reporting in connection with the contribution of certain terminal, pipeline and storage assets to MPLX. The operating results for these assets are now reported in our Midstream segment. Previously, they were reported as part of our Refining & Marketing segment. Comparable prior period information has been recast to reflect our revised presentation. The results for the pipeline and storage assets were recast effective January 1, 2015, and the results for the terminal assets were recast effective April 1, 2016. Prior to these dates, these assets were not considered businesses and, therefore, there are no financial results from which to recast segment results.

We have three reportable segments: Refining & Marketing; Speedway; and Midstream. Each of these segments is organized and managed based upon the nature of the products and services it offers.

•

Refining & Marketing – refines crude oil and other feedstocks at our seven refineries in the Gulf Coast and Midwest regions of the United States, purchases refined products and ethanol for resale and distributes refined products through various means, including pipeline and marine transportation, terminal and storage services provided by our Midstream segment. We sell refined products to wholesale marketing customers domestically and internationally, to buyers on the spot market, to our Speedway segment and to independent entrepreneurs who operate Marathon^® retail outlets.


•	Speedway – sells transportation fuels and convenience merchandise in retail markets in the Midwest, East Coast and Southeast regions of the United States.


•	Midstream – includes the operations of MPLX and certain other related operations. The Midstream segment gathers, processes and transports natural gas; gathers, transports, fractionates, stores and markets NGLs; and transports and stores crude oil and refined products principally for the Refining & Marketing segment.

Segment income represents income from operations attributable to the reportable segments. Corporate administrative expenses, except for those attributable to MPLX, and costs related to certain non-operating assets are not allocated to the reportable segments. In addition, certain items that affect comparability (as determined by the chief operating decision maker) are not allocated to the reportable segments.



(In millions)	Refining & Marketing		Speedway		Midstream		Total
Three Months Ended September 30, 2017
Revenues:
Third party	$	13,573	$	4,895	$	585	$	19,053
Intersegment^(a)	2,904		1		369		3,274
Related party	155		2		—		157
Segment revenues	$	16,632	$	4,898	$	954	$	22,484
Segment income from operations^(b)	$	1,097	$	209	$	355	$	1,661
Income from equity method investments	6		20		57		83
Depreciation and amortization^(c)	266		68		169		503
Capital expenditures and investments^(d)	198		108		453		759



(In millions)	Refining & Marketing		Speedway		Midstream		Total
Three Months Ended September 30, 2016
Revenues:
Third party	$	11,284	$	4,848	$	484	$	16,616
Intersegment^(a)	2,798		1		346		3,145
Related party	2		—		—		2
Segment revenues	$	14,084	$	4,849	$	830	$	19,763
Segment income from operations^(b)	$	252	$	209	$	310	$	771
Income from equity method investments^(c)	8		—		51		59
Depreciation and amortization^(c)	267		71		155		493
Capital expenditures and investments^(d)	251		71		410		732



(In millions)	Refining & Marketing		Speedway		Midstream		Total
Nine Months Ended September 30, 2017
Revenues:
Third party	$	37,485	$	14,070	$	1,665	$	53,220
Intersegment^(a)	8,302		3		1,076		9,381
Related party	452		6		—		458
Segment revenues	$	46,239	$	14,079	$	2,741	$	63,059
Segment income from operations^(b)	$	1,589	$	583	$	996	$	3,168
Income from equity method investments	10		54		139		203
Depreciation and amortization^(c)	805		197		528		1,530
Capital expenditures and investments^(d)(e)	570		221		2,017		2,808



(In millions)	Refining & Marketing		Speedway		Midstream		Total
Nine Months Ended September 30, 2016
Revenues:
Third party	$	31,192	$	13,663	$	1,324	$	46,179
Intersegment^(a)	7,872		2		911		8,785
Related party	5		—		—		5
Segment revenues	$	39,069	$	13,665	$	2,235	$	54,969
Segment income from operations^(b)(f)	$	1,191	$	569	$	752	$	2,512
Income from equity method investments^(c)	10		—		110		120
Depreciation and amortization^(c)	801		203		448		1,452
Capital expenditures and investments^(d)	756		191		1,179		2,126


^(a)	Management believes intersegment transactions were conducted under terms comparable to those with unaffiliated parties.


^(b)	Corporate overhead expenses attributable to MPLX are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.


^(c)	Differences between segment totals and MPC totals represent amounts related to unallocated items and are included in “Items not allocated to segments” in the reconciliation below.


^(d)	Capital expenditures include changes in capital accruals, acquisitions (including any goodwill) and investments in affiliates.


^(e)	The Midstream segment includes $220 million for the acquisition of the Ozark pipeline and an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system for the nine months ended September 30, 2017.


^(f)	The Refining & Marketing and Speedway segments include inventory LCM benefits of $345 million and $25 million, respectively, for the nine months ended September 30, 2016.

The following reconciles segment income from operations to income before income taxes as reported in the consolidated statements of income:



	Three Months Ended September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
Segment income from operations	$	1,661		$	771		$	3,168		$	2,512
Items not allocated to segments:
Corporate and other unallocated items^(a)	(86		)	(65		)	(251		)	(194		)
Pension settlement expenses	(1		)	(4		)	(2		)	(7		)
Litigation^(b)	—			—			(86		)	—
Impairments^(c)	2			(267		)	21			(486		)
Net interest and other financial income (costs)	(157		)	(141		)	(465		)	(420		)
Income before income taxes	$	1,419		$	294		$	2,385		$	1,405


^(a)	Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets, except for corporate overhead expenses attributable to MPLX, which are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.


^(b)	See Note 21 for further information on litigation matters.


^(c)	2017 includes MPC’s share of gains related to the sale of assets remaining from the Sandpiper pipeline project. 2016 relates to impairments of goodwill and equity method investments.

The following reconciles segment capital expenditures and investments to total capital expenditures:



	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions)	2017		2016		2017		2016
Segment capital expenditures and investments	$	759	$	732	$	2,808	$	2,126
Less investments in equity method investees^(a)	53		69		730		383
Plus items not allocated to segments:
Corporate and Other	19		14		53		59
Capitalized interest	13		15		39		47
Total capital expenditures^(b)	$	738	$	692	$	2,170	$	1,849


^(a)	The nine months ended September 30, 2017 includes an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system. The nine months ended September 30, 2016 includes an adjustment of $143 million to the fair value of equity method investments acquired in connection with the MarkWest Merger.


^(b)	Capital expenditures include changes in capital accruals. See Note 17 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.

Other Items

9 Months Ended

Sep. 30, 2017

Other Items

Net interest and other financial income (costs) was:



	Three Months Ended September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
Interest income	$	7		$	3		$	16		$	5
Interest expense	(172		)	(153		)	(508		)	(455		)
Interest capitalized	14			15			47			47
Other financial costs	(6		)	(6		)	(20		)	(17		)
Net interest and other financial income (costs)	$	(157	)	$	(141	)	$	(465	)	$	(420	)

Income Taxes	9 Months Ended
Income Taxes	Sep. 30, 2017
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The combined federal, state and foreign income tax rate was 29 percent and 26 percent for the three months ended September 30, 2017 and 2016, respectively, and 30 percent and 34 percent for the nine months ended September 30, 2017 and 2016, respectively. The effective tax rate for the three and nine months ended September 30, 2017 was less than the U.S. statutory rate of 35 percent primarily due to certain permanent tax differences related to net income attributable to noncontrolling interests, the domestic manufacturing deduction and equity compensation offset by state and local tax expense. The effective tax rate for the three months ended September 30, 2016 varies from the U.S. statutory rate of 35 percent primarily due to the effects of a lower forecasted annual effective tax rate as compared to the forecasted rate used for the first six months of 2016. The effective tax rate for the nine months ended September 30, 2016 is slightly less than the U.S. statutory rate of 35 percent primarily due to certain permanent tax differences related to the net income attributable to noncontrolling interests (including their proportional share of the goodwill impairment charge recorded by MPLX), the domestic manufacturing deduction and state and local tax expense. We are continuously undergoing examination of our income tax returns, which have been completed through the 2007 tax year for state returns and the 2009 tax year for our U.S. federal return. As of September 30, 2017, we had $19 million of unrecognized tax benefits. Prior to its spin-off on June 30, 2011, Marathon Petroleum Corporation was included in the Marathon Oil Corporation (“Marathon Oil”) federal income tax returns for all applicable years. During the third quarter 2017, Marathon Oil received a notice of Final Partnership Administrative Adjustment (“FPAA”) from the IRS for taxable year 2010, relating to certain partnership transactions. Marathon Oil intends to file a U.S. Tax Court petition disputing these adjustments during the fourth quarter of 2017. We received an FPAA for taxable years 2011-2014 for items resulting from the Marathon Oil IRS dispute discussed above. We intend to file a U.S. Tax Court petition in the fourth quarter of 2017 for tax years 2011-2014 to dispute these corollary adjustments. We continue to believe that the issue in dispute is more likely than not to be fully sustained and therefore, no liability has been accrued for this matter. Pursuant to our tax sharing agreement with Marathon Oil, the unrecognized tax benefits related to pre-spinoff operations for which Marathon Oil was the taxpayer remain the responsibility of Marathon Oil and we have indemnified Marathon Oil accordingly. See Note 21 for indemnification information.

Inventories

9 Months Ended

Sep. 30, 2017

Inventory Disclosure [Abstract]

Inventories



(In millions)	September 30, 2017		December 31, 2016
Crude oil and refinery feedstocks	$	2,147	$	2,208
Refined products	2,706		2,810
Materials and supplies	486		485
Merchandise	154		153
Total	$	5,493	$	5,656

Inventories are carried at the lower of cost or market value. The cost of inventories of crude oil and refinery feedstocks, refined products and merchandise is determined primarily under the LIFO method. There were no liquidations of LIFO inventories for the nine months ended September 30, 2017.

Property, Plant and Equipment

9 Months Ended

Sep. 30, 2017

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment



(In millions)	September 30, 2017		December 31, 2016^(a)
Refining & Marketing	$	19,174	$	18,590
Speedway	5,233		5,078
Midstream	14,489		13,521
Corporate and Other	822		817
Total	39,718		38,006
Less accumulated depreciation	13,682		12,241
Property, plant and equipment, net	$	26,036	$	25,765


^(a)	Prior period balances have been recast in connection with the March 1, 2017 contribution of assets to MPLX. See Note 1for additional information.

Fair Value Measurements

9 Months Ended

Sep. 30, 2017

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Values—Recurring

The following tables present assets and liabilities accounted for at fair value on a recurring basis as of September 30, 2017 and December 31, 2016 by fair value hierarchy level. We have elected to offset the fair value amounts recognized for multiple derivative contracts executed with the same counterparty, including any related cash collateral as shown below; however, fair value amounts by hierarchy level are presented on a gross basis in the following tables.



	September 30, 2017
	Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Netting and Collateral^(a)			Net Carrying Value on Balance Sheet^(b)		Collateral Pledged Not Offset
Commodity derivative instruments, assets	$	257	$	—	$	—	$	(257	)	$	—	$	22
Other assets	3		—		—		N/A			3		—
Total assets at fair value	$	260	$	—	$	—	$	(257	)	$	3	$	22

Commodity derivative instruments, liabilities^(c)	$	296	$	—	$	5	$	(296	)	$	5	$	—
Embedded derivatives in commodity contracts^(c)	—		—		52		—			52		—
Total liabilities at fair value	$	296	$	—	$	57	$	(296	)	$	57	$	—



	December 31, 2016
	Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Netting and Collateral^(a)			Net Carrying Value on Balance Sheet^(b)		Collateral Pledged Not Offset
Commodity derivative instruments, assets	$	688	$	—	$	—	$	(688	)	$	—	$	126
Other assets	2		—		—		N/A			2		—
Total assets at fair value	$	690	$	—	$	—	$	(688	)	$	2	$	126

Commodity derivative instruments, liabilities	$	712	$	—	$	6	$	(712	)	$	6	$	—
Embedded derivatives in commodity contracts^(c)	—		—		54		—			54		—
Contingent consideration, liability^(d)	—		—		130		N/A			130		—
Total liabilities at fair value	$	712	$	—	$	190	$	(712	)	$	190	$	—


^(a)	Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of September 30, 2017, cash collateral of $39 million was netted with the mark-to-market derivative liabilities. As of December 31, 2016, $24 million was netted with mark-to-market derivative liabilities.


^(b)	We have no derivative contracts that are subject to master netting arrangements reflected gross on the balance sheet.


^(c)	Level 3 includes $15 million and $13 million classified as current at September 30, 2017 and December 31, 2016, respectively.


^(d)	Includes $130 million classified as current at December 31, 2016.

Commodity derivatives in Level 1 are exchange-traded contracts for crude oil and refined products measured at fair value with a market approach using the close-of-day settlement prices for the market. Commodity derivatives are covered under master netting agreements with an unconditional right to offset. Collateral deposits in futures commission merchant accounts covered by master netting agreements related to Level 1 commodity derivatives are classified as Level 1 in the fair value hierarchy.

Level 3 instruments include OTC NGL contracts and embedded derivatives in commodity contracts. The embedded derivative liability relates to a natural gas purchase agreement embedded in a keep‑whole processing agreement. The fair value calculation for these Level 3 instruments used significant unobservable inputs including: (1) NGL prices interpolated and extrapolated due to inactive markets ranging from $0.27 to $1.22 per gallon and (2) the probability of renewal of 50 percent for the first five-year term and 75 percent for the second five-year term of the gas purchase agreement and the related keep-whole processing agreement. For these contracts, increases in forward NGL prices result in a decrease in the fair value of the derivative assets and an increase in the fair value of the derivative liabilities. The forward prices for the individual NGL products generally increase or decrease in a positive correlation with one another. Increases or decreases in forward NGL prices result in an increase or decrease in the fair value of the embedded derivative. An increase in the probability of renewal would result in an increase in the fair value of the related embedded derivative liability.

The contingent consideration represents the fair value of the remaining amount we expected to pay to BP related to the earnout provision associated with our 2013 acquisition of BP’s refinery in Texas City, Texas and related logistics and marketing assets. The fair value of the remaining contingent consideration as of December 31, 2016 was estimated using an income approach and was therefore a Level 3 liability. The fair value calculation used significant unobservable inputs including: (1) an estimate of forecasted monthly refinery throughput volumes; (2) an internal and external monthly crack spread forecast; and (3) a range of risk-adjusted discount rates. The fair value of the contingent consideration liability was reassessed each quarter, with changes in fair value recorded in cost of revenues. The balance of $131 million was paid on April 12, 2017. On the consolidated statements of cash flows for the nine months ended September 30, 2017, $89 million of the contingent earnout payment is included as a financing activity with the remainder included as an operating activity.

The following is a reconciliation of the beginning and ending balances recorded for liabilities classified as Level 3 in the fair value hierarchy.



	Three Months Ended September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
Beginning balance	$	41		$	171		$	190		$	342
Contingent consideration payment	—			—			(131		)	(200		)
Unrealized and realized losses included in net income	22			6			8			33
Settlements of derivative instruments	(6		)	(1		)	(10		)	1
Ending balance	$	57		$	176		$	57		$	176

The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets still held at the end of period:
Derivative instruments	$	17		$	4		$	8		$	19
Contingent consideration agreement	—			2			1			11
Total	$	17		$	6		$	9		$	30

Fair Values – Reported

The following table summarizes financial instruments on the basis of their nature, characteristics and risk at September 30, 2017 and December 31, 2016, excluding the derivative financial instruments and contingent consideration reported above.



	September 30, 2017				December 31, 2016
(In millions)	Fair Value		Carrying Value		Fair Value		Carrying Value
Financial assets:
Investments	$	25	$	2	$	25	$	2
Other	25		25		21		21
Total financial assets	$	50	$	27	$	46	$	23
Financial liabilities:
Long-term debt^(a)	$	13,690	$	12,544	$	10,892	$	10,297
Deferred credits and other liabilities	121		107		121		109
Total financial liabilities	$	13,811	$	12,651	$	11,013	$	10,406


^(a)	Excludes capital leases and debt issuance costs; however, includes amount classified as debt due within one year.

Our current assets and liabilities include financial instruments, the most significant of which are trade accounts receivable and payables. We believe the carrying values of our current assets and liabilities approximate fair value. Our fair value assessment incorporates a variety of considerations, including (1) the short-term duration of the instruments, (2) our investment-grade credit rating and (3) our historical incurrence of and expected future insignificance of bad debt expense, which includes an evaluation of counterparty credit risk.

Fair values of our financial assets included in investments and other financial assets and of our financial liabilities included in deferred credits and other liabilities are measured primarily using an income approach and most inputs are internally generated, which results in a Level 3 classification. Estimated future cash flows are discounted using a rate deemed appropriate to obtain the fair value. Other financial assets primarily consist of environmental remediation receivables. Deferred credits and other liabilities primarily consist of a liability resulting from a financing arrangement for the construction of MPLX’s steam methane reformer (“SMR”) at the Javelina gas processing and fractionation complex in Corpus Christi, Texas, insurance liabilities and environmental remediation liabilities.

Fair value of fixed-rate long-term debt is measured using a market approach, based upon the average of quotes for our debt from major financial institutions and a third-party valuation service. Because these quotes cannot be independently verified to the market, they are considered Level 3 inputs. Fair value of variable-rate long-term debt approximates the carrying value.

- Definition

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

+ References + Details

Derivatives

9 Months Ended

Sep. 30, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives

For further information regarding the fair value measurement of derivative instruments, including any effect of master netting agreements or collateral, see Note 14. We do not designate any of our commodity derivative instruments as hedges for accounting purposes.

Derivatives that are not designated as accounting hedges may include commodity derivatives used to hedge price risk on (1) inventories, (2) fixed price sales of refined products, (3) the acquisition of foreign-sourced crude oil, (4) the acquisition of ethanol for blending with refined products, (5) the sale of NGLs and (6) the purchase of natural gas.

The following table presents the gross fair values of derivative instruments, excluding cash collateral, and where they appear on the consolidated balance sheets as of September 30, 2017 and December 31, 2016:



(In millions)	September 30, 2017
Balance Sheet Location	Asset		Liability
Commodity derivatives
Other current assets	$	257	$	296
Other current liabilities^(a)	—		15
Deferred credits and other liabilities^(a)	—		42



(In millions)	December 31, 2016
Balance Sheet Location	Asset		Liability
Commodity derivatives
Other current assets	$	688	$	712
Other current liabilities^(a)	—		13
Deferred credits and other liabilities^(a)	—		47


^(a)	Includes embedded derivatives.

The tables below summarize open commodity derivative contracts for crude oil and refined products as of September 30, 2017.



	Position	Total Barrels (In thousands)
Crude Oil^(a)
Exchange-traded	Long	33,043
Exchange-traded	Short	(34,428	)


^{(a )}	94 percent of the exchange-traded contracts expire in the fourth quarter of 2017.



	Position	Total Gallons (In thousands)
Refined Products^(a)
Exchange-traded	Long	316,764
Exchange-traded	Short	(227,388	)
OTC	Short	(33,388	)


^{(a )}	100 percent of the exchange-traded contracts expire in the fourth quarter of 2017.

The following table summarizes the effect of all commodity derivative instruments in our consolidated statements of income:



	Gain (Loss)						Gain (Loss)
(In millions)	Three Months Ended September 30,						Nine Months Ended September 30,
Income Statement Location	2017			2016			2017			2016
Sales and other operating revenues	$	(10	)	$	(3	)	$	8		$	(4	)
Cost of revenues	1			(20		)	(30		)	(91		)
Total	$	(9	)	$	(23	)	$	(22	)	$	(95	)

Debt

9 Months Ended

Sep. 30, 2017

Debt Disclosure [Abstract]

Debt

Our outstanding borrowings at September 30, 2017 and December 31, 2016 consisted of the following:



(In millions)	September 30, 2017			December 31, 2016
Marathon Petroleum Corporation:
Commercial paper	$	—		$	—
364-day bank revolving credit facility due July 2018	—			—
Trade receivables securitization facility due July 2019	—			—
Bank revolving credit facility due 2022	—			—
Term loan agreement due 2019	—			200
Senior notes, 2.700% due December 2018	600			600
Senior notes, 3.400% due December 2020	650			650
Senior notes, 5.125% due March 2021	1,000			1,000
Senior notes, 3.625%, due September 2024	750			750
Senior notes, 6.500%, due March 2041	1,250			1,250
Senior notes, 4.750%, due September 2044	800			800
Senior notes, 5.850% due December 2045	250			250
Senior notes, 5.000%, due September 2054	400			400
MPLX LP:
MPLX term loan facility due 2019	—			250
MPLX bank revolving credit facility due 2022	420			—
MPLX senior notes, 5.500%, due February 2023	710			710
MPLX senior notes, 4.500%, due July 2023	989			989
MPLX senior notes, 4.875%, due December 2024	1,149			1,149
MPLX senior notes, 4.000%, due February 2025	500			500
MPLX senior notes, 4.875%, due June 2025	1,189			1,189
MarkWest senior notes, 4.500% - 5.500%, due 2023 - 2025	63			63
MPLX senior notes, 4.125%, due March 2027	1,250			—
MPLX senior notes, 5.200%, due March 2047	1,000			—
Capital lease obligations due 2017-2028	299			319
Total	13,269			11,069
Unamortized debt issuance costs	(61		)	(44		)
Unamortized discount^(a)	(426		)	(453		)
Amounts due within one year	(29		)	(28		)
Total long-term debt due after one year	$	12,753		$	10,544


^(a)	Includes $386 million and $420 million of unamortized discount as of September 30, 2017 and December 31, 2016, respectively, related to the difference between the fair value and the principal amount of assumed MarkWest debt.

During the nine months ended September 30, 2017, we borrowed and repaid $300 million under the commercial paper program. At September 30, 2017, we had no amounts outstanding under the commercial paper program.

At September 30, 2017, we had no amounts outstanding under our trade receivables securitization facility.

MPC Bank Revolving Credit Facilities

On July 21, 2017, we entered into credit agreements with a syndicate of lenders to replace MPC’s previous $2.5 billion four-year bank revolving credit facility and $1 billion 364-day revolving credit facility. The new credit agreements provide for a $2.5 billion five-year bank revolving credit facility that expires in July 2022 and a $1 billion 364-day bank revolving credit facility that expires in July 2018. The financial covenants and the interest rate terms contained in the new credit agreements are substantially the same as those contained in the previous bank revolving credit facilities.

There were no borrowings or letters of credit outstanding under the MPC bank revolving credit facility at September 30, 2017.

MPC Term Loan Agreement

On March 31, 2017, we repaid the remaining $200 million outstanding under the MPC term loan agreement with available cash on hand. Under the provisions of the MPC term loan agreement, the loan may be prepaid in whole or in part without premium or penalty. The maturity date of the MPC term loan agreement was September 24, 2019.

MPLX Credit Agreement

On July 21, 2017, MPLX entered into a credit agreement to replace its previous $2 billion five-year bank revolving credit facility with a $2.25 billion five-year bank revolving credit facility that expires in July 2022. The financial covenants and the interest rate terms contained in the new credit agreement are substantially the same as those contained in the previous bank revolving credit facility.

Additionally, on July 19, 2017, MPLX prepaid the entire outstanding principal amount of its $250 million term loan with cash on hand.

During the nine months ended September 30, 2017, MPLX borrowed $420 million under the MPLX bank revolving credit facility, at an average interest rate of 2.7 percent, and made no repayments. At September 30, 2017, MPLX had $420 million outstanding borrowings and $3 million letters of credit outstanding under the MPLX bank revolving credit facility, resulting in total availability of $1.83 billion.

MPLX Senior Notes

On February 10, 2017, MPLX completed a public offering of $1.25 billion aggregate principal amount of 4.125% unsecured senior notes due March 2027 and $1.0 billion aggregate principal amount of 5.200% unsecured senior notes due March 2047. The net proceeds, which were approximately $2.22 billion after deducting underwriting discounts, were used by MPLX to fund the $1.5 billion cash portion of the consideration paid to MPC for the dropdown of assets on March 1, 2017, as well as for general partnership purposes. Interest is payable semi-annually in arrears on March 1 and September 1 of each year, commencing on September 1, 2017.

Supplemental Cash Flow Information

9 Months Ended

Sep. 30, 2017

Supplemental Cash Flow Elements [Abstract]

Supplemental Cash Flow Information



	Nine Months Ended September 30,
(In millions)	2017		2016
Net cash provided by operating activities included:
Interest paid (net of amounts capitalized)	$	446	$	400
Net income taxes paid to (refunded from) taxing authorities	383		28
Non-cash investing and financing activities:
Contribution of assets to joint venture^(a)	337		—


^(a)	MarkWest’s contribution of assets to Sherwood Midstream and Sherwood Midstream Holdings. See Note 4.

The consolidated statements of cash flows exclude changes to the consolidated balance sheets that did not affect cash. The following is a reconciliation of additions to property, plant and equipment to total capital expenditures:



	Nine Months Ended September 30,
(In millions)	2017			2016
Additions to property, plant and equipment per consolidated statements of cash flows	$	1,928		$	2,147
Asset retirement expenditures	1			4
Decrease in capital accruals	(9		)	(169		)
Total capital expenditures before acquisitions	1,920			1,982
Acquisitions^(a)	250			(133		)
Total capital expenditures	$	2,170		$	1,849


^(a)	The nine months ended September 30, 2017 reflects primarily the acquisition of the Ozark pipeline. The nine months ended September 30, 2016 reflects adjustments to the fair values of the property, plant and equipment, intangibles and goodwill acquired in connection with the MarkWest Merger.

Accumulated Other Comprehensive Loss

9 Months Ended

Sep. 30, 2017

Accumulated Other Comprehensive Loss

The following table shows the changes in accumulated other comprehensive loss by component. Amounts in parentheses indicate debits.



(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge		Workers Compensation			Total
Balance as of December 31, 2015	$	(255	)	$	(70	)	$	4	$	3		$	(318	)
Other comprehensive income (loss) before reclassifications	(8		)	1			—		—			(7		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit^(a)	(35		)	(2		)	—		—			(37		)
– actuarial loss^(a)	28			1			—		—			29
– settlement loss^(a)	7			—			—		—			7
Other^(b)	—			—			—		(1		)	(1		)
Tax effect	—			—			—		—			—
Other comprehensive income (loss)	(8		)	—			—		(1		)	(9		)
Balance as of September 30, 2016	$	(263	)	$	(70	)	$	4	$	2		$	(327	)



(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge		Workers Compensation			Total
Balance as of December 31, 2016	$	(233	)	$	(7	)	$	4	$	2		$	(234	)
Other comprehensive income (loss) before reclassifications	(2		)	—			—		—			(2		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit^(a)	(29		)	(2		)	—		—			(31		)
– actuarial loss/(gain)^(a)	27			(1		)	—		—			26
– settlement loss^(a)	2			—			—		—			2
Other^(b)	—			—			—		(2		)	(2		)
Tax effect	—			1			—		1			2
Other comprehensive income (loss)	(2		)	(2		)	—		(1		)	(5		)
Balance as of September 30, 2017	$	(235	)	$	(9	)	$	4	$	1		$	(239	)


^(a)	These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 19.


^(b)	This amount was reclassified out of accumulated other comprehensive loss and is included in selling, general and administrative on the consolidated statements of income.

Defined Benefit Pension and Other Postretirement Plans

9 Months Ended

Sep. 30, 2017

Retirement Benefits [Abstract]

Defined Benefit Pension and Other Postretirement Plans

The following summarizes the components of net periodic benefit costs:



	Three Months Ended September 30,
	Pension Benefits						Other Benefits
(In millions)	2017			2016			2017		2016
Components of net periodic benefit cost:
Service cost	$	33		$	29		$	6	$	8
Interest cost	19			18			8		9
Expected return on plan assets	(25		)	(24		)	—		—
Amortization – prior service credit	(10		)	(12		)	—		(1		)
– actuarial loss	9			10			—		—
– settlement loss	1			4			—		—
Net periodic benefit cost	$	27		$	25		$	14	$	16



	Nine Months Ended September 30,
	Pension Benefits						Other Benefits
(In millions)	2017			2016			2017			2016
Components of net periodic benefit cost:
Service cost	$	99		$	86		$	19		$	24
Interest cost	56			55			23			26
Expected return on plan assets	(75		)	(73		)	—			—
Amortization – prior service credit	(29		)	(35		)	(2		)	(2		)
– actuarial loss/(gain)	27			28			(1		)	1
– settlement loss	2			7			—			—
Net periodic benefit cost	$	80		$	68		$	39		$	49

During the nine months ended September 30, 2017, we chose to make a $120 million voluntary contribution to our funded pension plans. Benefit payments related to unfunded pension and other postretirement benefit plans were $7 million and $23 million, respectively, during the nine months ended September 30, 2017.

Stock-Based Compensation Plans

9 Months Ended

Sep. 30, 2017

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Stock-Based Compensation Plans

Stock Option Awards

The following table presents a summary of our stock option award activity for the nine months ended September 30, 2017:



	Number of Shares		Weighted Average Exercise Price
Outstanding at December 31, 2016	9,531,440		$	28.93
Granted	1,214,112		50.57
Exercised	(1,356,217	)	21.89
Forfeited, canceled or expired	(78,386	)	41.97
Outstanding at September 30, 2017	9,310,949		32.66

The grant date fair value of stock option awards granted during the nine months ended September 30, 2017 was $13.42 per share. The fair value of stock options granted to our employees is estimated on the date of the grant using the Black Scholes option-pricing model, which employs various assumptions.

Restricted Stock Awards

The following table presents a summary of restricted stock award activity for the nine months ended September 30, 2017:



	Shares of Restricted Stock (“RS”)				Restricted Stock Units (“RSU”)
	Number of Shares		Weighted Average Grant Date Fair Value		Number of Units		Weighted Average Grant Date Fair Value
Outstanding at December 31, 2016	1,250,343		$	41.51	361,117		$	28.26
Granted	574,602		50.20		28,573		51.94
RS’s Vested/RSU’s Issued	(522,454	)	42.48		(79,635	)	24.54
Forfeited	(83,806	)	44.29		(13,750	)	50.20
Outstanding at September 30, 2017	1,218,685		45.00		296,305		30.52

Performance Unit Awards

The following table presents a summary of the activity for performance unit awards to be settled in shares for the nine months ended September 30, 2017:



	Number of Units		Weighted Average Grant Date Fair Value
Outstanding at December 31, 2016	6,255,178		$	0.78
Granted	2,584,750		0.92
Exercised	(1,854,728	)	0.85
Canceled	(99,658	)	0.78
Outstanding at September 30, 2017	6,885,542		0.81

The performance unit awards granted during the nine months ended September 30, 2017 have a grant date fair value of $0.92 per unit, as calculated using a Monte Carlo valuation model.

MPLX Awards

During the nine months ended September 30, 2017, MPLX granted equity-based compensation awards under the MPLX LP 2012 Incentive Compensation Plan. The compensation expense for these awards is not material to our consolidated financial statements.

Commitments and Contingencies	9 Months Ended
Commitments and Contingencies	Sep. 30, 2017
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies We are the subject of, or a party to, a number of pending or threatened legal actions, contingencies and commitments involving a variety of matters, including laws and regulations relating to the environment. Some of these matters are discussed below. For matters for which we have not recorded a liability, we are unable to estimate a range of possible loss because the issues involved have not been fully developed through pleadings, discovery or court proceedings. However, the ultimate resolution of some of these contingencies could, individually or in the aggregate, be material. Environmental matters—We are subject to federal, state, local and foreign laws and regulations relating to the environment. These laws generally provide for control of pollutants released into the environment and require responsible parties to undertake remediation of hazardous waste disposal sites and certain other locations including presently or formerly owned or operated retail marketing sites. Penalties may be imposed for noncompliance. At September 30, 2017 and December 31, 2016, accrued liabilities for remediation totaled $117 million and $132 million, respectively. It is not presently possible to estimate the ultimate amount of all remediation costs that might be incurred or the penalties if any that may be imposed. Receivables for recoverable costs from certain states, under programs to assist companies in clean-up efforts related to underground storage tanks at presently or formerly owned or operated retail marketing sites, were $45 million and $58 million at September 30, 2017 and December 31, 2016, respectively. We are involved in a number of environmental enforcement matters arising in the ordinary course of business. While the outcome and impact on us cannot be predicted with certainty, management believes the resolution of these environmental matters will not, individually or collectively, have a material adverse effect on our consolidated results of operations, financial position or cash flows. MarkWest Environmental Proceeding – In July 2015, representatives from the EPA and the United States Department of Justice conducted a raid on a pipeline launcher/receiver site of MarkWest Liberty Midstream & Resources, L.L.C., a wholly-owned subsidiary of MPLX (“MarkWest Liberty Midstream”), utilized for pipeline maintenance operations in Washington County, Pennsylvania pursuant to a search warrant issued by a magistrate of the United States District Court for the Western District of Pennsylvania. As part of this initiative, the U.S. Attorney’s Office for the Western District of Pennsylvania, with the assistance of EPA’s Criminal Investigation Division proceeded with an investigation of MarkWest’s launcher/receiver, pipeline and compressor station operations. In response to the investigation, MarkWest initiated independent studies which demonstrated that there was no risk to worker safety and no threat of public harm associated with MarkWest Liberty Midstream’s launcher/receiver operations. These findings were supported by a subsequent inspection and review by the Occupational Safety and Health Administration. After providing these studies, and other substantial documentation related to MarkWest Liberty Midstream's pipeline and compressor stations, and arranging site visits and conducting several meetings with the government’s representatives, on September 13, 2016, the U.S. Attorney’s Office for the Western District of Pennsylvania rendered a declination decision, dropping its criminal investigation and declining to pursue charges in this matter. MarkWest Liberty Midstream continues to discuss with the EPA and the State of Pennsylvania civil enforcement allegations associated with permitting or other related regulatory obligations for its launcher/receiver and compressor station facilities in the region. In connection with these discussions, MarkWest Liberty Midstream received an initial proposal from the EPA to settle all civil claims associated with this matter for the combination of a proposed cash penalty of approximately $2.4 million and proposed supplemental environmental projects with an estimated cost of approximately $3.6 million. MarkWest Liberty Midstream has submitted a response asserting that this action involves novel issues surrounding primarily minor source emissions from facilities that the agencies themselves considered de minimis and were not the subject of regulation and consequently that the settlement proposal is excessive. In connection with these negotiations, MarkWest Liberty Midstream has received a revised settlement proposal from the EPA which proposes to lower the proposed cash penalty to approximately $1.2 million and the estimated cost of proposed supplemental environmental projects to an estimated cost of approximately $1.6 million. MarkWest Liberty Midstream will continue to negotiate with the EPA regarding the amount and scope of the proposed settlement. Other Lawsuits—On August 1, 2017, we entered into binding settlement agreements with the plaintiffs and co-defendants to settle four lawsuits brought forth by the plaintiffs alleging personal injuries from a fire that occurred at our Galveston Bay refinery on January 11, 2016. The other co-defendants in this litigation were contractors that were engaged by us to provide services at our Galveston Bay refinery. We recorded a liability for our losses under the settlement agreements which resulted in a charge of $86 million in the second quarter of 2017. We are vigorously pursuing recovery of such losses, as well as defense costs, through indemnification from a significant contractor who is not party to the settlement agreements. In May 2015, the Kentucky attorney general filed a lawsuit against our wholly-owned subsidiary, MPC LP in the United States District Court for the Western District of Kentucky asserting claims under federal and state antitrust statutes, the Kentucky Consumer Protection Act, and state common law. The complaint, as amended in July 2015, alleges that MPC LP used deed restrictions, supply agreements with customers and exchange agreements with competitors to unreasonably restrain trade in areas within Kentucky and seeks declaratory relief, unspecified damages, civil penalties, restitution and disgorgement of profits. At this early stage, the ultimate outcome of this litigation remains uncertain, and neither the likelihood of an unfavorable outcome nor the ultimate liability, if any, can be determined, and we are unable to estimate a reasonably possible loss (or range of loss) for this matter. We intend to vigorously defend ourselves in this matter. In May 2007, the Kentucky attorney general filed a lawsuit against us and Marathon Oil in state court in Franklin County, Kentucky for alleged violations of Kentucky’s emergency pricing and consumer protection laws following Hurricanes Katrina and Rita in 2005. The lawsuit alleges that we overcharged customers by $89 million during September and October 2005. The complaint seeks disgorgement of these sums, as well as penalties, under Kentucky’s emergency pricing and consumer protection laws. We are vigorously defending this litigation. We believe that this is the first lawsuit for damages and injunctive relief under the Kentucky emergency pricing laws to progress this far and it contains many novel issues. In May 2011, the Kentucky attorney general amended his complaint to include a request for immediate injunctive relief as well as unspecified damages and penalties related to our wholesale gasoline pricing in April and May 2011 under statewide price controls that were activated by the Kentucky governor on April 26, 2011 and which have since expired. The court denied the attorney general’s request for immediate injunctive relief, and the remainder of the 2011 claims likely will be resolved along with those dating from 2005. If the lawsuit is resolved unfavorably in its entirety, it could materially impact our consolidated results of operations, financial position or cash flows. However, management does not believe the ultimate resolution of this litigation will have a material adverse effect. We are also a party to a number of other lawsuits and other proceedings arising in the ordinary course of business. While the ultimate outcome and impact to us cannot be predicted with certainty, we believe that the resolution of these other lawsuits and proceedings will not have a material adverse effect on our consolidated financial position, results of operations or cash flows. Guarantees—We have provided certain guarantees, direct and indirect, of the indebtedness of other companies. Under the terms of most of these guarantee arrangements, we would be required to perform should the guaranteed party fail to fulfill its obligations under the specified arrangements. In addition to these financial guarantees, we also have various performance guarantees related to specific agreements. Guarantees related to indebtedness of equity method investees—MPC and MPLX hold interests in an offshore oil port, LOOP, and MPLX holds an interest in a crude oil pipeline system, LOCAP. Both LOOP and LOCAP have secured various project financings with throughput and deficiency agreements. Under the agreements, MPC, as a shipper, is required to advance funds if the investees are unable to service their debt. Any such advances are considered prepayments of future transportation charges. The duration of the agreements vary but tend to follow the terms of the underlying debt, which extend through 2037. Our maximum potential undiscounted payments under these agreements for the debt principal totaled $160 million as of September 30, 2017. We hold an interest in a refined products pipeline through our investment in Centennial, and have guaranteed our portion of the payment of Centennial’s principal, interest and prepayment costs, if applicable, under a Master Shelf Agreement, which is scheduled to expire in 2024. The guarantee arose in order for Centennial to obtain adequate financing. Our maximum potential undiscounted payments under this agreement for debt principal totaled $22 million as of September 30, 2017. In connection with our 50 percent indirect interest in Crowley Ocean Partners, we have agreed to conditionally guarantee our portion of the obligations of the joint venture and its subsidiaries under a senior secured term loan agreement. The term loan agreement provides for loans of up to $325 million to finance the acquisition of four product tankers. MPC’s liability under the guarantee for each vessel is conditioned upon the occurrence of certain events, including if we cease to maintain an investment grade credit rating or the charter for the relevant product tanker ceases to be in effect and is not replaced by a charter with an investment grade company on certain defined commercial terms. As of September 30, 2017, our maximum potential undiscounted payments under this agreement for debt principal totaled $163 million. In connection with our 50 percent indirect interest in Crowley Blue Water Partners, we have agreed to provide a conditional guarantee of up to 50 percent of its outstanding debt balance in the event there is no charter agreement in place with an investment grade customer for the entity’s three vessels as well as other financial support in certain circumstances. The maximum exposure under these arrangements is 50 percent of the amount of the debt, which was $139 million as of September 30, 2017. Marathon Oil indemnifications—In conjunction with our spinoff from Marathon Oil, we have entered into arrangements with Marathon Oil providing indemnities and guarantees with recorded values of $2 million as of September 30, 2017, which consist of unrecognized tax benefits related to MPC, its consolidated subsidiaries and the refining, marketing and transportation business operations prior to our spinoff which are not already reflected in the unrecognized tax benefits described in Note 11, and other contingent liabilities Marathon Oil may incur related to taxes. Furthermore, the separation and distribution agreement and other agreements with Marathon Oil to effect our spinoff provide for cross-indemnities between Marathon Oil and us. In general, Marathon Oil is required to indemnify us for any liabilities relating to Marathon Oil’s historical oil and gas exploration and production operations, oil sands mining operations and integrated gas operations, and we are required to indemnify Marathon Oil for any liabilities relating to Marathon Oil’s historical refining, marketing and transportation operations. The terms of these indemnifications are indefinite and the amounts are not capped. Other guarantees—We have entered into other guarantees with maximum potential undiscounted payments totaling $93 million as of September 30, 2017, which primarily consist of a commitment to contribute cash to an equity method investee for certain catastrophic events, up to $50 million per event, in lieu of procuring insurance coverage, a commitment to fund a share of the bonds issued by a government entity for construction of public utilities in the event that other industrial users of the facility default on their utility payments and leases of assets containing general lease indemnities and guaranteed residual values. General guarantees associated with dispositions – Over the years, we have sold various assets in the normal course of our business. Certain of the related agreements contain performance and general guarantees, including guarantees regarding inaccuracies in representations, warranties, covenants and agreements, and environmental and general indemnifications that require us to perform upon the occurrence of a triggering event or condition. These guarantees and indemnifications are part of the normal course of selling assets. We are typically not able to calculate the maximum potential amount of future payments that could be made under such contractual provisions because of the variability inherent in the guarantees and indemnities. Most often, the nature of the guarantees and indemnities is such that there is no appropriate method for quantifying the exposure because the underlying triggering event has little or no past experience upon which a reasonable prediction of the outcome can be based. Contractual commitments and contingencies—At September 30, 2017, our contractual commitments to acquire property, plant and equipment and advance funds to equity method investees totaled $694 million. Certain natural gas processing and gathering arrangements require us to construct natural gas processing plants, natural gas gathering pipelines and NGL pipelines and contain certain fees and charges if specified construction milestones are not achieved for reasons other than force majeure. In certain cases, certain producer customers may have the right to cancel the processing arrangements with us if there are significant delays that are not due to force majeure. As of September 30, 2017, management does not believe there are any indications that we will not be able to meet the construction milestones, that force majeure does not apply, or that such fees and charges will otherwise be triggered.

Supplementary Statistics

9 Months Ended

Sep. 30, 2017

Text Block [Abstract]

Supplementary Statistics

Supplementary Statistics (Unaudited)



	Three Months Ended September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
Income from Operations by segment
Refining & Marketing^(a)(b)	$	1,097		$	252		$	1,589		$	1,191
Speedway^(b)	209			209			583			569
Midstream^(a)(c)	355			310			996			752
Items not allocated to segments:
Corporate and other unallocated items^(a)(c)	(86		)	(65		)	(251		)	(194		)
Pension settlement expenses	(1		)	(4		)	(2		)	(7		)
Litigation	—			—			(86		)	—
Impairments^(d)	2			(267		)	21			(486		)
Income from operations	$	1,576		$	435		$	2,850		$	1,825
Capital Expenditures and Investments^(e)
Refining & Marketing	$	198		$	251		$	570		$	756
Speedway	108			71			221			191
Midstream^(f)	453			410			2,017			1,179
Corporate and Other^(g)	32			29			92			106
Total	$	791		$	761		$	2,900		$	2,232

^(a)

We revised our operating segment presentation in the first quarter of 2017 in connection with the contribution of certain terminal, pipeline and storage assets to MPLX. The operating results for these assets, which were previously included in the Refining & Marketing segment, are now included in the Midstream segment. Comparable prior period information has been recast to reflect our revised presentation. The results for the pipeline and storage assets were recast effective January 1, 2015, and the results for the terminal assets were recast effective April 1, 2016. Prior to these dates, these assets were not considered businesses and, therefore, there are no financial results from which to recast segment results.


^(b)	The Refining & Marketing and Speedway segments include inventory LCM benefits of $345 million and $25 million, respectively, for the nine months ended September 30, 2016.


^(c)	Corporate overhead expenses attributable to MPLX are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.


^(d)	2017 includes MPC’s share of gains related to the sale of assets remaining from the Sandpiper pipeline project. 2016 relates to impairments of goodwill and equity method investments.


^(e)	Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates.


^(f)	The nine months ended September 30, 2017 includes $220 million for the acquisition of the Ozark pipeline and an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system.


^(g)	Includes capitalized interest of $13 million and $15 million for the three months ended September 30, 2017 and 2016, respectively, and $39 million and $47 million for the nine months ended September 30, 2017 and 2016, respectively.

Supplementary Statistics (Unaudited)



	Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
MPC Consolidated Refined Product Sales Volumes (mbpd)^(a)	2,357		2,316		2,272		2,274
Refining & Marketing Operating Statistics
Refining & Marketing refined product sales volume (mbpd)^(b)	2,357		2,307		2,263		2,265
Refining & Marketing gross margin (dollars per barrel)^(c)(d)	$	14.14	$	10.67	$	12.42	$	11.11
Crude oil capacity utilization percent^(e)	102		100		96		95
Refinery throughputs (mbpd):^(f)
Crude oil refined	1,845		1,791		1,741		1,708
Other charge and blendstocks	172		135		176		156
Total	2,017		1,926		1,917		1,864
Sour crude oil throughput percent	57		59		61		60
WTI-priced crude oil throughput percent	23		20		20		20
Refined product yields (mbpd):^(f)
Gasoline	939		907		910		908
Distillates	673		647		627		616
Propane	38		38		35		35
Feedstocks and special products	298		253		285		245
Heavy fuel oil	45		43		36		36
Asphalt	67		70		64		58
Total	2,060		1,958		1,957		1,898
Refinery direct operating costs (dollars per barrel):^(g)
Planned turnaround and major maintenance	$	1.20	$	1.62	$	1.69	$	1.72
Depreciation and amortization	1.34		1.42		1.44		1.46
Other manufacturing^(h)	3.83		4.01		4.10		4.03
Total	$	6.37	$	7.05	$	7.23	$	7.21
Refining & Marketing Operating Statistics By Region - Gulf Coast
Refinery throughputs (mbpd):⁽ⁱ⁾
Crude oil refined	1,123		1,073		1,041		1,057
Other charge and blendstocks	217		185		219		199
Total	1,340		1,258		1,260		1,256
Sour crude oil throughput percent	69		72		75		73
WTI-priced crude oil throughput percent	14		8		10		7
Refined product yields (mbpd):⁽ⁱ⁾
Gasoline	538		511		525		530
Distillates	438		411		393		407
Propane	25		27		25		26
Feedstocks and special products	326		289		310		283
Heavy fuel oil	31		30		24		24
Asphalt	19		17		17		15
Total	1,377		1,285		1,294		1,285
Refinery direct operating costs (dollars per barrel):^(g)
Planned turnaround and major maintenance	$	0.90	$	2.05	$	1.86	$	1.87
Depreciation and amortization	1.05		1.14		1.15		1.13
Other manufacturing^(h)	3.52		3.70		3.81		3.62
Total	$	5.47	$	6.89	$	6.82	$	6.62



Supplementary Statistics (Unaudited)
	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Refining & Marketing Operating Statistics By Region – Midwest
Refinery throughputs (mbpd):⁽ⁱ⁾
Crude oil refined	722			718			700			651
Other charge and blendstocks	35			39			31			37
Total	757			757			731			688
Sour crude oil throughput percent	38			39			41			39
WTI-priced crude oil throughput percent	38			39			34			41
Refined product yields (mbpd):⁽ⁱ⁾
Gasoline	401			396			385			378
Distillates	235			236			234			209
Propane	14			13			11			11
Feedstocks and special products	50			51			47			40
Heavy fuel oil	15			13			13			12
Asphalt	48			53			47			43
Total	763			762			737			693
Refinery direct operating costs (dollars per barrel):^(g)
Planned turnaround and major maintenance	$	1.60		$	0.72		$	1.22		$	1.26
Depreciation and amortization	1.72			1.72			1.80			1.90
Other manufacturing^(h)	3.96			4.04			4.19			4.29
Total	$	7.28		$	6.48		$	7.21		$	7.45
Speedway Operating Statistics^(j)
Convenience stores at period-end	2,734			2,773
Gasoline and distillate sales (millions of gallons)	1,464			1,575			4,332			4,605
Gasoline and distillate gross margin (dollars per gallon)^(k)	$	0.1772		$	0.1773		$	0.1727		$	0.1668
Merchandise sales (in millions)	$	1,295		$	1,338		$	3,693		$	3,777
Merchandise gross margin (in millions)	$	374		$	386		$	1,065		$	1,085
Merchandise gross margin percent	28.9		%	28.9		%	28.8		%	28.7		%
Same store gasoline sales volume (period over period)	(3.1		%)	(0.6		%)	(1.6		%)	0.2		%
Same store merchandise sales (period over period)^(l)	0.3		%	4.0		%	1.5		%	3.0		%
Midstream Operating Statistics
Crude oil and refined product pipeline throughputs (mbpd)^(m)	3,562			3,113			3,299			2,953
Terminal throughput (mbpd)⁽ⁿ⁾	1,496			1,517			1,470			1,510
Gathering system throughput (MMcf/d)^(o)	3,729			3,306			3,415			3,313
Natural gas processed (MMcf/d)^(o)	6,581			5,906			6,336			5,691
C2 (ethane) + NGLs (natural gas liquids) fractionated (mbpd)^(o)	397			348			384			330


^(a)	Total average daily volumes of refined product sales to wholesale, branded and retail customers.


^(b)	Includes intersegment sales.


^(c)	Sales revenue less cost of refinery inputs and purchased products, divided by total refinery throughputs.


^(d)	Excludes LCM inventory valuation adjustments. Comparable prior period information for gross margin has been recast in connection with the contribution of certain pipeline assets to MPLX on March 1, 2017.


^(e)	Based on calendar day capacity, which is an annual average that includes downtime for planned maintenance and other normal operating activities.


^(f)	Excludes inter-refinery volumes of 80 mbpd and 89 mbpd for the three months ended September 30, 2017 and 2016, respectively, and 74 mbpd and 80 mbpd for the nine months ended September 30, 2017 and 2016, respectively.


^(g)	Per barrel of total refinery throughputs.


^(h)	Includes utilities, labor, routine maintenance and other operating costs.


⁽ⁱ⁾	Includes inter-refinery transfer volumes.


^(j)	Third quarter and year-to-date 2017 operating statistics do not reflect any information for the 41 travel centers contributed to PFJ Southeast, whereas they are reflected in the third quarter and year-to-date 2016 operating statistics.


^(k)	Excludes LCM inventory valuation adjustments. The price paid by consumers less the cost of refined products, including transportation, consumer excise taxes and bankcard processing fees, divided by gasoline and distillate sales volume.


^(l)	Excludes cigarettes.


^(m)	Includes common-carrier pipelines and private pipelines contributed to MPLX, excluding equity method investments.


⁽ⁿ⁾	Includes the results of the terminal assets contributed to MPLX from the date the assets became a business, April 1, 2016.


^(o)	Includes amounts related to unconsolidated equity method investments on a 100 percent basis.

Description of the Business and Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2017
Accounting Policies [Abstract]
Use of estimates	These interim consolidated financial statements are unaudited; however, in the opinion of our management, these statements reflect all adjustments necessary for a fair statement of the results for the periods reported. All such adjustments are of a normal, recurring nature unless otherwise disclosed. These interim consolidated financial statements, including the notes, have been prepared in accordance with the rules of the SEC applicable to interim period financial statements and do not include all of the information and disclosures required by GAAP for complete financial statements.
Inventories	Inventories are carried at the lower of cost or market value. The cost of inventories of crude oil and refinery feedstocks, refined products and merchandise is determined primarily under the LIFO method.
Derivative instruments	Derivatives that are not designated as accounting hedges may include commodity derivatives used to hedge price risk on (1) inventories, (2) fixed price sales of refined products, (3) the acquisition of foreign-sourced crude oil, (4) the acquisition of ethanol for blending with refined products, (5) the sale of NGLs and (6) the purchase of natural gas.
Stock-based compensation arrangements	The fair value of stock options granted to our employees is estimated on the date of the grant using the Black Scholes option-pricing model, which employs various assumptions.

MPLX LP (Tables)

9 Months Ended

Sep. 30, 2017

Noncontrolling Interest [Abstract]

Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Table Text Block]

Changes in MPC’s equity and the offsetting changes to noncontrolling interest resulting from changes in MPC’s and the noncontrolling interest’s ownership interests in MPLX were as follows:



	Nine Months Ended September 30,
(In millions)	2017			2016
Transfers (to) from noncontrolling interest
Increase (decrease) in MPC's additional paid in capital for the issuance of MPLX LP common units to the public	$	25		$	(43	)
Increase in MPC's additional paid in capital for the issuance of MPLX LP common units and general partner units to MPC	113			—
Net transfers (to) from noncontrolling interests	138			(43		)
Tax impact	(26		)	(70		)
Change in MPC's additional paid-in capital, net of tax	$	112		$	(113	)

Acquisitions and Investments (Tables)

9 Months Ended

Sep. 30, 2017

Business Combinations [Abstract]

Business Acquisition, Pro Forma Information [Table Text Block]

The amounts of revenue and income from operations associated with the acquisition included in our consolidated statements of income, since the March 1, 2017 acquisition date, are as follows:



	Three Months Ended September 30,		Seven Months Ended September 30,
(In millions)	2017		2017
Sales and other operating revenues (including consumer excise taxes)	$	19	$	45
Income from operations	6		17

Related Party Transactions (Tables)

9 Months Ended

Sep. 30, 2017

Sales to Related Parties

Sales to related parties were as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions)	2017		2016		2017		2016
PFJ Southeast	$	155	$	—	$	451	$	—
Other equity method investees	2		2		7		5
Total	$	157	$	2	$	458	$	5

Other Income From Related Parties

Other income from related parties, which is included in “Other income” on the accompanying consolidated statements of income, were as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions)	2017		2016		2017		2016
MarkWest Utica EMG	$	5	$	5	$	13	$	12
Ohio Gathering	4		5		12		12
Other equity method investees	4		2		14		7
Total	$	13	$	12	$	39	$	31

Purchases From Related Parties

Purchases from related parties were as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions)	2017		2016		2017		2016
Crowley Blue Water Partners	$	16	$	16	$	44	$	22
Crowley Ocean Partners	20		15		59		32
Explorer	7		4		7		12
Illinois Extension Pipeline	26		27		75		82
LOCAP	6		6		17		18
LOOP	14		14		53		42
TAAE	22		9		53		29
TACE	9		10		34		39
TAME	20		23		58		67
Other equity method investees	8		4		20		16
Total	$	148	$	128	$	420	$	359

Receivables From Related Parties

Receivables from related parties, which are included in “Receivables, less allowance for doubtful accounts” on the accompanying consolidated balance sheets, were as follows:



(In millions)	September 30, 2017		December 31, 2016
MarkWest Utica EMG	$	2	$	2
Ohio Gathering	2		2
PFJ Southeast	32		40
Other equity method investees	4		1
Total	$	40	$	45

Payables To Related Parties

Payables to related parties, which are included in “Accounts payable” on the accompanying consolidated balance sheets, were as follows:



(In millions)	September 30, 2017		December 31, 2016
Illinois Extension Pipeline	$	9	$	9
LOCAP	2		2
LOOP	5		6
MarkWest Utica EMG	30		24
TAAE	2		2
TACE	1		4
TAME	2		4
Other equity method investees	13		2
Total	$	64	$	53

Income per Common Share (Tables)

9 Months Ended

Sep. 30, 2017

Earnings Per Share [Abstract]

Summary of Earnings Per Common Share

MPC grants certain incentive compensation awards to employees and non-employee directors that are considered to be participating securities. Due to the presence of participating securities, we have calculated our earnings per share using the two-class method.



	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions, except per share data)	2017		2016		2017		2016
Basic earnings per share:
Allocation of earnings:
Net income attributable to MPC	$	903	$	145	$	1,416	$	947
Income allocated to participating securities	—		—		1		1
Income available to common stockholders – basic	$	903	$	145	$	1,415	$	946
Weighted average common shares outstanding	504		527		514		528
Basic earnings per share	$	1.79	$	0.28	$	2.75	$	1.79
Diluted earnings per share:
Allocation of earnings:
Net income attributable to MPC	$	903	$	145	$	1,416	$	947
Income allocated to participating securities	—		—		1		1
Income available to common stockholders – diluted	$	903	$	145	$	1,415	$	946
Weighted average common shares outstanding	504		527		514		528
Effect of dilutive securities	4		3		4		3
Weighted average common shares, including dilutive effect	508		530		518		531
Diluted earnings per share	$	1.77	$	0.27	$	2.73	$	1.78

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share

The following table summarizes the shares that were anti-dilutive and, therefore, were excluded from the diluted share calculation.



	Three Months Ended September 30,		Nine Months Ended September 30,
(In millions)	2017	2016	2017	2016
Shares issued under stock-based compensation plans	1	3	1	3

Equity (Tables)

9 Months Ended

Sep. 30, 2017

Income From Operations Attributable To Operating Segments

Share Repurchases

Total share repurchases were as follows for the three and nine months ended September 30, 2017 and 2016:



	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions, except per share data)	2017		2016		2017		2016
Number of shares repurchased	8		1		31		4
Cash paid for shares repurchased	$	452	$	51	$	1,622	$	177
Effective average cost per delivered share	$	53.85	$	42.76	$	52.16	$	41.14

Segment Information (Tables)

9 Months Ended

Sep. 30, 2017

Segment Reporting [Abstract]

Segment income represents income from operations attributable to the reportable segments. Corporate administrative expenses, except for those attributable to MPLX, and costs related to certain non-operating assets are not allocated to the reportable segments. In addition, certain items that affect comparability (as determined by the chief operating decision maker) are not allocated to the reportable segments.



(In millions)	Refining & Marketing		Speedway		Midstream		Total
Three Months Ended September 30, 2017
Revenues:
Third party	$	13,573	$	4,895	$	585	$	19,053
Intersegment^(a)	2,904		1		369		3,274
Related party	155		2		—		157
Segment revenues	$	16,632	$	4,898	$	954	$	22,484
Segment income from operations^(b)	$	1,097	$	209	$	355	$	1,661
Income from equity method investments	6		20		57		83
Depreciation and amortization^(c)	266		68		169		503
Capital expenditures and investments^(d)	198		108		453		759



(In millions)	Refining & Marketing		Speedway		Midstream		Total
Three Months Ended September 30, 2016
Revenues:
Third party	$	11,284	$	4,848	$	484	$	16,616
Intersegment^(a)	2,798		1		346		3,145
Related party	2		—		—		2
Segment revenues	$	14,084	$	4,849	$	830	$	19,763
Segment income from operations^(b)	$	252	$	209	$	310	$	771
Income from equity method investments^(c)	8		—		51		59
Depreciation and amortization^(c)	267		71		155		493
Capital expenditures and investments^(d)	251		71		410		732



(In millions)	Refining & Marketing		Speedway		Midstream		Total
Nine Months Ended September 30, 2017
Revenues:
Third party	$	37,485	$	14,070	$	1,665	$	53,220
Intersegment^(a)	8,302		3		1,076		9,381
Related party	452		6		—		458
Segment revenues	$	46,239	$	14,079	$	2,741	$	63,059
Segment income from operations^(b)	$	1,589	$	583	$	996	$	3,168
Income from equity method investments	10		54		139		203
Depreciation and amortization^(c)	805		197		528		1,530
Capital expenditures and investments^(d)(e)	570		221		2,017		2,808



(In millions)	Refining & Marketing		Speedway		Midstream		Total
Nine Months Ended September 30, 2016
Revenues:
Third party	$	31,192	$	13,663	$	1,324	$	46,179
Intersegment^(a)	7,872		2		911		8,785
Related party	5		—		—		5
Segment revenues	$	39,069	$	13,665	$	2,235	$	54,969
Segment income from operations^(b)(f)	$	1,191	$	569	$	752	$	2,512
Income from equity method investments^(c)	10		—		110		120
Depreciation and amortization^(c)	801		203		448		1,452
Capital expenditures and investments^(d)	756		191		1,179		2,126


^(a)	Management believes intersegment transactions were conducted under terms comparable to those with unaffiliated parties.


^(b)	Corporate overhead expenses attributable to MPLX are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.


^(c)	Differences between segment totals and MPC totals represent amounts related to unallocated items and are included in “Items not allocated to segments” in the reconciliation below.


^(d)	Capital expenditures include changes in capital accruals, acquisitions (including any goodwill) and investments in affiliates.


^(e)	The Midstream segment includes $220 million for the acquisition of the Ozark pipeline and an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system for the nine months ended September 30, 2017.


^(f)	The Refining & Marketing and Speedway segments include inventory LCM benefits of $345 million and $25 million, respectively, for the nine months ended September 30, 2016.

Reconciliation Of Segment Income From Operations To Income Before Income Taxes

The following reconciles segment income from operations to income before income taxes as reported in the consolidated statements of income:



	Three Months Ended September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
Segment income from operations	$	1,661		$	771		$	3,168		$	2,512
Items not allocated to segments:
Corporate and other unallocated items^(a)	(86		)	(65		)	(251		)	(194		)
Pension settlement expenses	(1		)	(4		)	(2		)	(7		)
Litigation^(b)	—			—			(86		)	—
Impairments^(c)	2			(267		)	21			(486		)
Net interest and other financial income (costs)	(157		)	(141		)	(465		)	(420		)
Income before income taxes	$	1,419		$	294		$	2,385		$	1,405


^(a)	Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets, except for corporate overhead expenses attributable to MPLX, which are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.


^(b)	See Note 21 for further information on litigation matters.


^(c)	2017 includes MPC’s share of gains related to the sale of assets remaining from the Sandpiper pipeline project. 2016 relates to impairments of goodwill and equity method investments.

Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures

The following reconciles segment capital expenditures and investments to total capital expenditures:



	Three Months Ended September 30,				Nine Months Ended September 30,
(In millions)	2017		2016		2017		2016
Segment capital expenditures and investments	$	759	$	732	$	2,808	$	2,126
Less investments in equity method investees^(a)	53		69		730		383
Plus items not allocated to segments:
Corporate and Other	19		14		53		59
Capitalized interest	13		15		39		47
Total capital expenditures^(b)	$	738	$	692	$	2,170	$	1,849


^(a)	The nine months ended September 30, 2017 includes an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system. The nine months ended September 30, 2016 includes an adjustment of $143 million to the fair value of equity method investments acquired in connection with the MarkWest Merger.


^(b)	Capital expenditures include changes in capital accruals. See Note 17 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.

Other Items (Tables)

9 Months Ended

Sep. 30, 2017

Other Income and Expenses [Abstract]

Net Interest And Other Financial Income (Costs)

Net interest and other financial income (costs) was:



	Three Months Ended September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
Interest income	$	7		$	3		$	16		$	5
Interest expense	(172		)	(153		)	(508		)	(455		)
Interest capitalized	14			15			47			47
Other financial costs	(6		)	(6		)	(20		)	(17		)
Net interest and other financial income (costs)	$	(157	)	$	(141	)	$	(465	)	$	(420	)

Inventories (Tables)

9 Months Ended

Sep. 30, 2017

Inventory Disclosure [Abstract]

Summary Of Inventories



(In millions)	September 30, 2017		December 31, 2016
Crude oil and refinery feedstocks	$	2,147	$	2,208
Refined products	2,706		2,810
Materials and supplies	486		485
Merchandise	154		153
Total	$	5,493	$	5,656

Property, Plant and Equipment (Tables)

9 Months Ended

Sep. 30, 2017

Property, Plant and Equipment [Abstract]

Summary Of Property, Plant And Equipment



(In millions)	September 30, 2017		December 31, 2016^(a)
Refining & Marketing	$	19,174	$	18,590
Speedway	5,233		5,078
Midstream	14,489		13,521
Corporate and Other	822		817
Total	39,718		38,006
Less accumulated depreciation	13,682		12,241
Property, plant and equipment, net	$	26,036	$	25,765


^(a)	Prior period balances have been recast in connection with the March 1, 2017 contribution of assets to MPLX. See Note 1for additional information.

Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2017

Fair Value Disclosures [Abstract]

Assets and Liabilities Accounted for at Fair Value on Recurring Basis

The following tables present assets and liabilities accounted for at fair value on a recurring basis as of September 30, 2017 and December 31, 2016 by fair value hierarchy level. We have elected to offset the fair value amounts recognized for multiple derivative contracts executed with the same counterparty, including any related cash collateral as shown below; however, fair value amounts by hierarchy level are presented on a gross basis in the following tables.



	September 30, 2017
	Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Netting and Collateral^(a)			Net Carrying Value on Balance Sheet^(b)		Collateral Pledged Not Offset
Commodity derivative instruments, assets	$	257	$	—	$	—	$	(257	)	$	—	$	22
Other assets	3		—		—		N/A			3		—
Total assets at fair value	$	260	$	—	$	—	$	(257	)	$	3	$	22

Commodity derivative instruments, liabilities^(c)	$	296	$	—	$	5	$	(296	)	$	5	$	—
Embedded derivatives in commodity contracts^(c)	—		—		52		—			52		—
Total liabilities at fair value	$	296	$	—	$	57	$	(296	)	$	57	$	—



	December 31, 2016
	Fair Value Hierarchy
(In millions)	Level 1		Level 2		Level 3		Netting and Collateral^(a)			Net Carrying Value on Balance Sheet^(b)		Collateral Pledged Not Offset
Commodity derivative instruments, assets	$	688	$	—	$	—	$	(688	)	$	—	$	126
Other assets	2		—		—		N/A			2		—
Total assets at fair value	$	690	$	—	$	—	$	(688	)	$	2	$	126

Commodity derivative instruments, liabilities	$	712	$	—	$	6	$	(712	)	$	6	$	—
Embedded derivatives in commodity contracts^(c)	—		—		54		—			54		—
Contingent consideration, liability^(d)	—		—		130		N/A			130		—
Total liabilities at fair value	$	712	$	—	$	190	$	(712	)	$	190	$	—


^(a)	Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of September 30, 2017, cash collateral of $39 million was netted with the mark-to-market derivative liabilities. As of December 31, 2016, $24 million was netted with mark-to-market derivative liabilities.


^(b)	We have no derivative contracts that are subject to master netting arrangements reflected gross on the balance sheet.


^(c)	Level 3 includes $15 million and $13 million classified as current at September 30, 2017 and December 31, 2016, respectively.


^(d)	Includes $130 million classified as current at December 31, 2016.

Reconciliation of Net Beginning and Ending Balances Recorded for Net Assets and Liabilities Classified as Level 3

The following is a reconciliation of the beginning and ending balances recorded for liabilities classified as Level 3 in the fair value hierarchy.



	Three Months Ended September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
Beginning balance	$	41		$	171		$	190		$	342
Contingent consideration payment	—			—			(131		)	(200		)
Unrealized and realized losses included in net income	22			6			8			33
Settlements of derivative instruments	(6		)	(1		)	(10		)	1
Ending balance	$	57		$	176		$	57		$	176

The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets still held at the end of period:
Derivative instruments	$	17		$	4		$	8		$	19
Contingent consideration agreement	—			2			1			11
Total	$	17		$	6		$	9		$	30

Financial Instruments at Fair Value, Excluding Derivative Financial Instruments and Contingent Consideration

The following table summarizes financial instruments on the basis of their nature, characteristics and risk at September 30, 2017 and December 31, 2016, excluding the derivative financial instruments and contingent consideration reported above.



	September 30, 2017				December 31, 2016
(In millions)	Fair Value		Carrying Value		Fair Value		Carrying Value
Financial assets:
Investments	$	25	$	2	$	25	$	2
Other	25		25		21		21
Total financial assets	$	50	$	27	$	46	$	23
Financial liabilities:
Long-term debt^(a)	$	13,690	$	12,544	$	10,892	$	10,297
Deferred credits and other liabilities	121		107		121		109
Total financial liabilities	$	13,811	$	12,651	$	11,013	$	10,406


^(a)	Excludes capital leases and debt issuance costs; however, includes amount classified as debt due within one year.

Derivatives (Tables)

9 Months Ended

Sep. 30, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Classification of Fair Values of Derivative Instruments, Excluding Cash Collateral

The following table presents the gross fair values of derivative instruments, excluding cash collateral, and where they appear on the consolidated balance sheets as of September 30, 2017 and December 31, 2016:



(In millions)	September 30, 2017
Balance Sheet Location	Asset		Liability
Commodity derivatives
Other current assets	$	257	$	296
Other current liabilities^(a)	—		15
Deferred credits and other liabilities^(a)	—		42



(In millions)	December 31, 2016
Balance Sheet Location	Asset		Liability
Commodity derivatives
Other current assets	$	688	$	712
Other current liabilities^(a)	—		13
Deferred credits and other liabilities^(a)	—		47


^(a)	Includes embedded derivatives.

Open Commodity Derivative Contracts

The tables below summarize open commodity derivative contracts for crude oil and refined products as of September 30, 2017.



	Position	Total Barrels (In thousands)
Crude Oil^(a)
Exchange-traded	Long	33,043
Exchange-traded	Short	(34,428	)


^{(a )}	94 percent of the exchange-traded contracts expire in the fourth quarter of 2017.



	Position	Total Gallons (In thousands)
Refined Products^(a)
Exchange-traded	Long	316,764
Exchange-traded	Short	(227,388	)
OTC	Short	(33,388	)


^{(a )}	100 percent of the exchange-traded contracts expire in the fourth quarter of 2017.

Effect of Commodity Derivative Instruments in Statements of Income

The following table summarizes the effect of all commodity derivative instruments in our consolidated statements of income:



	Gain (Loss)						Gain (Loss)
(In millions)	Three Months Ended September 30,						Nine Months Ended September 30,
Income Statement Location	2017			2016			2017			2016
Sales and other operating revenues	$	(10	)	$	(3	)	$	8		$	(4	)
Cost of revenues	1			(20		)	(30		)	(91		)
Total	$	(9	)	$	(23	)	$	(22	)	$	(95	)

- Definition

Tabular disclosure of pertinent information about a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. May include a combination of the type of instrument, risks being hedged, notional amount, hedge designation, related hedged item, inception date, maturity date, or other relevant item.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=84234895&loc=d3e41641-113959

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4B
-URI http://asc.fasb.org/extlink&oid=84234895&loc=SL5624163-113959

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=84234895&loc=d3e41678-113959

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=84234895&loc=d3e41638-113959

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1B
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+ Details

Debt (Tables)

9 Months Ended

Sep. 30, 2017

Debt Disclosure [Abstract]

Outstanding Borrowings

Our outstanding borrowings at September 30, 2017 and December 31, 2016 consisted of the following:



(In millions)	September 30, 2017			December 31, 2016
Marathon Petroleum Corporation:
Commercial paper	$	—		$	—
364-day bank revolving credit facility due July 2018	—			—
Trade receivables securitization facility due July 2019	—			—
Bank revolving credit facility due 2022	—			—
Term loan agreement due 2019	—			200
Senior notes, 2.700% due December 2018	600			600
Senior notes, 3.400% due December 2020	650			650
Senior notes, 5.125% due March 2021	1,000			1,000
Senior notes, 3.625%, due September 2024	750			750
Senior notes, 6.500%, due March 2041	1,250			1,250
Senior notes, 4.750%, due September 2044	800			800
Senior notes, 5.850% due December 2045	250			250
Senior notes, 5.000%, due September 2054	400			400
MPLX LP:
MPLX term loan facility due 2019	—			250
MPLX bank revolving credit facility due 2022	420			—
MPLX senior notes, 5.500%, due February 2023	710			710
MPLX senior notes, 4.500%, due July 2023	989			989
MPLX senior notes, 4.875%, due December 2024	1,149			1,149
MPLX senior notes, 4.000%, due February 2025	500			500
MPLX senior notes, 4.875%, due June 2025	1,189			1,189
MarkWest senior notes, 4.500% - 5.500%, due 2023 - 2025	63			63
MPLX senior notes, 4.125%, due March 2027	1,250			—
MPLX senior notes, 5.200%, due March 2047	1,000			—
Capital lease obligations due 2017-2028	299			319
Total	13,269			11,069
Unamortized debt issuance costs	(61		)	(44		)
Unamortized discount^(a)	(426		)	(453		)
Amounts due within one year	(29		)	(28		)
Total long-term debt due after one year	$	12,753		$	10,544


^(a)	Includes $386 million and $420 million of unamortized discount as of September 30, 2017 and December 31, 2016, respectively, related to the difference between the fair value and the principal amount of assumed MarkWest debt.

- Definition

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.22)
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+ Details

Supplemental Cash Flow Information (Tables)

9 Months Ended

Sep. 30, 2017

Supplemental Cash Flow Elements [Abstract]

Summary of Supplemental Cash Flow Information



	Nine Months Ended September 30,
(In millions)	2017		2016
Net cash provided by operating activities included:
Interest paid (net of amounts capitalized)	$	446	$	400
Net income taxes paid to (refunded from) taxing authorities	383		28
Non-cash investing and financing activities:
Contribution of assets to joint venture^(a)	337		—


^(a)	MarkWest’s contribution of assets to Sherwood Midstream and Sherwood Midstream Holdings. See Note 4.

Reconciliation of Additions to Property, Plant and Equipment to Total Capital Expenditures

The consolidated statements of cash flows exclude changes to the consolidated balance sheets that did not affect cash. The following is a reconciliation of additions to property, plant and equipment to total capital expenditures:



	Nine Months Ended September 30,
(In millions)	2017			2016
Additions to property, plant and equipment per consolidated statements of cash flows	$	1,928		$	2,147
Asset retirement expenditures	1			4
Decrease in capital accruals	(9		)	(169		)
Total capital expenditures before acquisitions	1,920			1,982
Acquisitions^(a)	250			(133		)
Total capital expenditures	$	2,170		$	1,849


^(a)	The nine months ended September 30, 2017 reflects primarily the acquisition of the Ozark pipeline. The nine months ended September 30, 2016 reflects adjustments to the fair values of the property, plant and equipment, intangibles and goodwill acquired in connection with the MarkWest Merger.

Accumulated Other Comprehensive Loss (Tables)

9 Months Ended

Sep. 30, 2017

Changes in Accumulated Other Comprehensive Loss by Component

The following table shows the changes in accumulated other comprehensive loss by component. Amounts in parentheses indicate debits.



(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge		Workers Compensation			Total
Balance as of December 31, 2015	$	(255	)	$	(70	)	$	4	$	3		$	(318	)
Other comprehensive income (loss) before reclassifications	(8		)	1			—		—			(7		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit^(a)	(35		)	(2		)	—		—			(37		)
– actuarial loss^(a)	28			1			—		—			29
– settlement loss^(a)	7			—			—		—			7
Other^(b)	—			—			—		(1		)	(1		)
Tax effect	—			—			—		—			—
Other comprehensive income (loss)	(8		)	—			—		(1		)	(9		)
Balance as of September 30, 2016	$	(263	)	$	(70	)	$	4	$	2		$	(327	)



(In millions)	Pension Benefits			Other Benefits			Gain on Cash Flow Hedge		Workers Compensation			Total
Balance as of December 31, 2016	$	(233	)	$	(7	)	$	4	$	2		$	(234	)
Other comprehensive income (loss) before reclassifications	(2		)	—			—		—			(2		)
Amounts reclassified from accumulated other comprehensive loss:
Amortization – prior service credit^(a)	(29		)	(2		)	—		—			(31		)
– actuarial loss/(gain)^(a)	27			(1		)	—		—			26
– settlement loss^(a)	2			—			—		—			2
Other^(b)	—			—			—		(2		)	(2		)
Tax effect	—			1			—		1			2
Other comprehensive income (loss)	(2		)	(2		)	—		(1		)	(5		)
Balance as of September 30, 2017	$	(235	)	$	(9	)	$	4	$	1		$	(239	)


^(a)	These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 19.


^(b)	This amount was reclassified out of accumulated other comprehensive loss and is included in selling, general and administrative on the consolidated statements of income.

Defined Benefit Pension and Other Postretirement Plans (Tables)

9 Months Ended

Sep. 30, 2017

Retirement Benefits [Abstract]

Components of Net Periodic Benefit Costs

The following summarizes the components of net periodic benefit costs:



	Three Months Ended September 30,
	Pension Benefits						Other Benefits
(In millions)	2017			2016			2017		2016
Components of net periodic benefit cost:
Service cost	$	33		$	29		$	6	$	8
Interest cost	19			18			8		9
Expected return on plan assets	(25		)	(24		)	—		—
Amortization – prior service credit	(10		)	(12		)	—		(1		)
– actuarial loss	9			10			—		—
– settlement loss	1			4			—		—
Net periodic benefit cost	$	27		$	25		$	14	$	16



	Nine Months Ended September 30,
	Pension Benefits						Other Benefits
(In millions)	2017			2016			2017			2016
Components of net periodic benefit cost:
Service cost	$	99		$	86		$	19		$	24
Interest cost	56			55			23			26
Expected return on plan assets	(75		)	(73		)	—			—
Amortization – prior service credit	(29		)	(35		)	(2		)	(2		)
– actuarial loss/(gain)	27			28			(1		)	1
– settlement loss	2			7			—			—
Net periodic benefit cost	$	80		$	68		$	39		$	49

Stock-Based Compensation Plans (Tables)

9 Months Ended

Sep. 30, 2017

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Summary of Stock Option Award Activity

The following table presents a summary of our stock option award activity for the nine months ended September 30, 2017:



	Number of Shares		Weighted Average Exercise Price
Outstanding at December 31, 2016	9,531,440		$	28.93
Granted	1,214,112		50.57
Exercised	(1,356,217	)	21.89
Forfeited, canceled or expired	(78,386	)	41.97
Outstanding at September 30, 2017	9,310,949		32.66

Summary of Restricted Stock Award Activity

The following table presents a summary of restricted stock award activity for the nine months ended September 30, 2017:



	Shares of Restricted Stock (“RS”)				Restricted Stock Units (“RSU”)
	Number of Shares		Weighted Average Grant Date Fair Value		Number of Units		Weighted Average Grant Date Fair Value
Outstanding at December 31, 2016	1,250,343		$	41.51	361,117		$	28.26
Granted	574,602		50.20		28,573		51.94
RS’s Vested/RSU’s Issued	(522,454	)	42.48		(79,635	)	24.54
Forfeited	(83,806	)	44.29		(13,750	)	50.20
Outstanding at September 30, 2017	1,218,685		45.00		296,305		30.52

Schedule of Performance Unit Awards

The following table presents a summary of the activity for performance unit awards to be settled in shares for the nine months ended September 30, 2017:



	Number of Units		Weighted Average Grant Date Fair Value
Outstanding at December 31, 2016	6,255,178		$	0.78
Granted	2,584,750		0.92
Exercised	(1,854,728	)	0.85
Canceled	(99,658	)	0.78
Outstanding at September 30, 2017	6,885,542		0.81

Supplementary Statistics (Tables)

9 Months Ended

Sep. 30, 2017

Text Block [Abstract]

Supplementary Statistics

Supplementary Statistics (Unaudited)



	Three Months Ended September 30,						Nine Months Ended September 30,
(In millions)	2017			2016			2017			2016
Income from Operations by segment
Refining & Marketing^(a)(b)	$	1,097		$	252		$	1,589		$	1,191
Speedway^(b)	209			209			583			569
Midstream^(a)(c)	355			310			996			752
Items not allocated to segments:
Corporate and other unallocated items^(a)(c)	(86		)	(65		)	(251		)	(194		)
Pension settlement expenses	(1		)	(4		)	(2		)	(7		)
Litigation	—			—			(86		)	—
Impairments^(d)	2			(267		)	21			(486		)
Income from operations	$	1,576		$	435		$	2,850		$	1,825
Capital Expenditures and Investments^(e)
Refining & Marketing	$	198		$	251		$	570		$	756
Speedway	108			71			221			191
Midstream^(f)	453			410			2,017			1,179
Corporate and Other^(g)	32			29			92			106
Total	$	791		$	761		$	2,900		$	2,232

^(a)

We revised our operating segment presentation in the first quarter of 2017 in connection with the contribution of certain terminal, pipeline and storage assets to MPLX. The operating results for these assets, which were previously included in the Refining & Marketing segment, are now included in the Midstream segment. Comparable prior period information has been recast to reflect our revised presentation. The results for the pipeline and storage assets were recast effective January 1, 2015, and the results for the terminal assets were recast effective April 1, 2016. Prior to these dates, these assets were not considered businesses and, therefore, there are no financial results from which to recast segment results.


^(b)	The Refining & Marketing and Speedway segments include inventory LCM benefits of $345 million and $25 million, respectively, for the nine months ended September 30, 2016.


^(c)	Corporate overhead expenses attributable to MPLX are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.


^(d)	2017 includes MPC’s share of gains related to the sale of assets remaining from the Sandpiper pipeline project. 2016 relates to impairments of goodwill and equity method investments.


^(e)	Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates.


^(f)	The nine months ended September 30, 2017 includes $220 million for the acquisition of the Ozark pipeline and an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system.


^(g)	Includes capitalized interest of $13 million and $15 million for the three months ended September 30, 2017 and 2016, respectively, and $39 million and $47 million for the nine months ended September 30, 2017 and 2016, respectively.

Operating Statistics

Supplementary Statistics (Unaudited)



	Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
MPC Consolidated Refined Product Sales Volumes (mbpd)^(a)	2,357		2,316		2,272		2,274
Refining & Marketing Operating Statistics
Refining & Marketing refined product sales volume (mbpd)^(b)	2,357		2,307		2,263		2,265
Refining & Marketing gross margin (dollars per barrel)^(c)(d)	$	14.14	$	10.67	$	12.42	$	11.11
Crude oil capacity utilization percent^(e)	102		100		96		95
Refinery throughputs (mbpd):^(f)
Crude oil refined	1,845		1,791		1,741		1,708
Other charge and blendstocks	172		135		176		156
Total	2,017		1,926		1,917		1,864
Sour crude oil throughput percent	57		59		61		60
WTI-priced crude oil throughput percent	23		20		20		20
Refined product yields (mbpd):^(f)
Gasoline	939		907		910		908
Distillates	673		647		627		616
Propane	38		38		35		35
Feedstocks and special products	298		253		285		245
Heavy fuel oil	45		43		36		36
Asphalt	67		70		64		58
Total	2,060		1,958		1,957		1,898
Refinery direct operating costs (dollars per barrel):^(g)
Planned turnaround and major maintenance	$	1.20	$	1.62	$	1.69	$	1.72
Depreciation and amortization	1.34		1.42		1.44		1.46
Other manufacturing^(h)	3.83		4.01		4.10		4.03
Total	$	6.37	$	7.05	$	7.23	$	7.21
Refining & Marketing Operating Statistics By Region - Gulf Coast
Refinery throughputs (mbpd):⁽ⁱ⁾
Crude oil refined	1,123		1,073		1,041		1,057
Other charge and blendstocks	217		185		219		199
Total	1,340		1,258		1,260		1,256
Sour crude oil throughput percent	69		72		75		73
WTI-priced crude oil throughput percent	14		8		10		7
Refined product yields (mbpd):⁽ⁱ⁾
Gasoline	538		511		525		530
Distillates	438		411		393		407
Propane	25		27		25		26
Feedstocks and special products	326		289		310		283
Heavy fuel oil	31		30		24		24
Asphalt	19		17		17		15
Total	1,377		1,285		1,294		1,285
Refinery direct operating costs (dollars per barrel):^(g)
Planned turnaround and major maintenance	$	0.90	$	2.05	$	1.86	$	1.87
Depreciation and amortization	1.05		1.14		1.15		1.13
Other manufacturing^(h)	3.52		3.70		3.81		3.62
Total	$	5.47	$	6.89	$	6.82	$	6.62



Supplementary Statistics (Unaudited)
	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Refining & Marketing Operating Statistics By Region – Midwest
Refinery throughputs (mbpd):⁽ⁱ⁾
Crude oil refined	722			718			700			651
Other charge and blendstocks	35			39			31			37
Total	757			757			731			688
Sour crude oil throughput percent	38			39			41			39
WTI-priced crude oil throughput percent	38			39			34			41
Refined product yields (mbpd):⁽ⁱ⁾
Gasoline	401			396			385			378
Distillates	235			236			234			209
Propane	14			13			11			11
Feedstocks and special products	50			51			47			40
Heavy fuel oil	15			13			13			12
Asphalt	48			53			47			43
Total	763			762			737			693
Refinery direct operating costs (dollars per barrel):^(g)
Planned turnaround and major maintenance	$	1.60		$	0.72		$	1.22		$	1.26
Depreciation and amortization	1.72			1.72			1.80			1.90
Other manufacturing^(h)	3.96			4.04			4.19			4.29
Total	$	7.28		$	6.48		$	7.21		$	7.45
Speedway Operating Statistics^(j)
Convenience stores at period-end	2,734			2,773
Gasoline and distillate sales (millions of gallons)	1,464			1,575			4,332			4,605
Gasoline and distillate gross margin (dollars per gallon)^(k)	$	0.1772		$	0.1773		$	0.1727		$	0.1668
Merchandise sales (in millions)	$	1,295		$	1,338		$	3,693		$	3,777
Merchandise gross margin (in millions)	$	374		$	386		$	1,065		$	1,085
Merchandise gross margin percent	28.9		%	28.9		%	28.8		%	28.7		%
Same store gasoline sales volume (period over period)	(3.1		%)	(0.6		%)	(1.6		%)	0.2		%
Same store merchandise sales (period over period)^(l)	0.3		%	4.0		%	1.5		%	3.0		%
Midstream Operating Statistics
Crude oil and refined product pipeline throughputs (mbpd)^(m)	3,562			3,113			3,299			2,953
Terminal throughput (mbpd)⁽ⁿ⁾	1,496			1,517			1,470			1,510
Gathering system throughput (MMcf/d)^(o)	3,729			3,306			3,415			3,313
Natural gas processed (MMcf/d)^(o)	6,581			5,906			6,336			5,691
C2 (ethane) + NGLs (natural gas liquids) fractionated (mbpd)^(o)	397			348			384			330


^(a)	Total average daily volumes of refined product sales to wholesale, branded and retail customers.


^(b)	Includes intersegment sales.


^(c)	Sales revenue less cost of refinery inputs and purchased products, divided by total refinery throughputs.


^(d)	Excludes LCM inventory valuation adjustments. Comparable prior period information for gross margin has been recast in connection with the contribution of certain pipeline assets to MPLX on March 1, 2017.


^(e)	Based on calendar day capacity, which is an annual average that includes downtime for planned maintenance and other normal operating activities.


^(f)	Excludes inter-refinery volumes of 80 mbpd and 89 mbpd for the three months ended September 30, 2017 and 2016, respectively, and 74 mbpd and 80 mbpd for the nine months ended September 30, 2017 and 2016, respectively.


^(g)	Per barrel of total refinery throughputs.


^(h)	Includes utilities, labor, routine maintenance and other operating costs.


⁽ⁱ⁾	Includes inter-refinery transfer volumes.


^(j)	Third quarter and year-to-date 2017 operating statistics do not reflect any information for the 41 travel centers contributed to PFJ Southeast, whereas they are reflected in the third quarter and year-to-date 2016 operating statistics.


^(k)	Excludes LCM inventory valuation adjustments. The price paid by consumers less the cost of refined products, including transportation, consumer excise taxes and bankcard processing fees, divided by gasoline and distillate sales volume.


^(l)	Excludes cigarettes.


^(m)	Includes common-carrier pipelines and private pipelines contributed to MPLX, excluding equity method investments.


⁽ⁿ⁾	Includes the results of the terminal assets contributed to MPLX from the date the assets became a business, April 1, 2016.


^(o)	Includes amounts related to unconsolidated equity method investments on a 100 percent basis.

MPLX LP (Detail) - MPLX LP	Sep. 30, 2017
Noncontrolling Interest [Line Items]
Ownership percentage of general partner interest	100.00%
Public's ownership interest in MPLX (in percentage)	69.60%
General Partner and Limited Partner
Noncontrolling Interest [Line Items]
MPC's partnership interest in MPLX (in percentage)	30.40%
General Partner
Noncontrolling Interest [Line Items]
MPC's partnership interest in MPLX (in percentage)	2.00%

MPLX LP - Reorganization Transactions (Details) - MPLX LP - USD ($) shares in Millions, $ in Millions	Sep. 01, 2017	Mar. 01, 2017	Sep. 01, 2016	Mar. 31, 2016
General partners' contributed capital			$ 225
Limited Partner
Units issued, number of units	19	13	7	23
General Partner and Limited Partner
Increase in ownership percentage by MPC			1.00%

MPLX LP - Private Placement of Preferred Units (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		9 Months Ended
	May 13, 2016	Sep. 30, 2017	Sep. 30, 2016
Noncontrolling Interest [Line Items]
Issuance of MPLX LP redeemable preferred units		$ 0	$ 984
MPLX LP \| Series A Convertible Preferred Units
Noncontrolling Interest [Line Items]
Sale of units (in number of preferred units)	30.8
Preferred units, dividend rate, percentage	6.50%
Issuance of MPLX LP redeemable preferred units	$ 984
Preferred units, distribution rate, per-dollar-amount	$ 0.528125
Preferred units, description	The MPLX Preferred Units are convertible into MPLX common units on a one for one basis after three years, at the purchasers’ option, and after four years at MPLX’s option, subject to certain conditions.
MPLX LP \| Series A Convertible Preferred Units \| Preferred Units
Noncontrolling Interest [Line Items]
Units issued, price per unit	$ 32.50

MPLX LP - Dropdowns to MPLX (Details) - MPLX LP - USD ($) shares in Thousands, $ in Millions	Sep. 01, 2017	Mar. 01, 2017	Sep. 01, 2016	Mar. 31, 2016
Noncontrolling Interest [Line Items]
Total fair value of consideration transferred	$ 1,050	$ 2,000
Limited Partner
Noncontrolling Interest [Line Items]
Units issued, number of units	19,000	13,000	7,000	23,000
Equity interest issued, value assigned	$ 630	$ 504		$ 600
General Partner
Noncontrolling Interest [Line Items]
Units issued, number of units	378	264		460
Cash and Cash Equivalents
Noncontrolling Interest [Line Items]
Payments to acquire business, gross	$ 420	$ 1,500

MPLX LP - Public Offerings (Details) - MPLX LP - USD ($) $ in Millions	Sep. 01, 2017	Mar. 01, 2017	Sep. 30, 2017	Feb. 10, 2017	Dec. 31, 2016
Cash and Cash Equivalents
Noncontrolling Interest [Line Items]
Payments to acquire business, gross	$ 420	$ 1,500
Senior Notes \| MPLX senior notes, 4.125%, due March 2027
Noncontrolling Interest [Line Items]
Long-term debt, gross			$ 1,250	$ 1,250	$ 0
Debt instrument, interest rate			4.125%	4.125%
Senior Notes \| MPLX senior notes, 5.200%, due March 2047
Noncontrolling Interest [Line Items]
Long-term debt, gross			$ 1,000	$ 1,000	$ 0
Debt instrument, interest rate			5.20%	5.20%

MPLX LP - ATM Program (Details) - USD ($) shares in Millions, $ in Millions	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Noncontrolling Interest [Line Items]
Net proceeds from issuance of MPLX LP common limited partners units	$ 473	$ 499
MPLX LP \| ATM Program
Noncontrolling Interest [Line Items]
Net proceeds from issuance of MPLX LP common limited partners units	473
Remaining authorized issuance amount	$ 1,740
MPLX LP \| ATM Program \| Limited Partners Common Units
Noncontrolling Interest [Line Items]
Sale of units (in number of common units)	14

MPLX LP - Noncontrolling Interest (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Impact from equity transactions of MPLX, net of tax	$ 447	$ 429
Additional Paid-in Capital
Increase (decrease) in MPC's additional paid in capital for the issuance of MPLX LP common units to the public	25	(43)
Increase in MPC's additional paid in capital for the issuance of MPLX LP common units and general partner units to MPC	113	0
Net transfers (to) from noncontrolling interests	138	(43)
Tax impact	(26)	(70)
Impact from equity transactions of MPLX, net of tax	$ 112	$ (113)

Acquisitions and Investments - Acquisition of Ozark Pipeline (Details) - Ozark Pipeline bbl / d in Thousands, $ in Millions	Mar. 01, 2017 USD ($) bbl / d in mi
Business Acquisition [Line Items]
Pipeline length \| mi	433
Pipeline diameter \| in	22
Crude oil throughput \| bbl / d	230
MPLX LP
Business Acquisition [Line Items]
Payments to acquire business, gross \| $	$ 219

Acquisitions and Investments - Revenue and Income from Operations (Details) - Ozark Pipeline - USD ($) $ in Millions	3 Months Ended	7 Months Ended
	Sep. 30, 2017	Sep. 30, 2017
Sales and other operating revenues (including consumer excise taxes)	$ 19	$ 45
Income from operations	$ 6	$ 17

Acquisitions and Investments - Formation of Travel Plaza Joint Venture (Details)
$ in Millions

3 Months Ended

9 Months Ended

Dec. 31, 2016

USD ($)

Store

Sep. 30, 2017

USD ($)

^[1]

Sep. 30, 2016

USD ($)

Schedule of Equity Method Investments [Line Items]

Schedule of Equity Method Investments [Line Items]

$ 337

$ 0

PFJ Southeast

PFJ Southeast | Property, Plant and Equipment

$ 273

Schedule of Equity Method Investments [Line Items]

Schedule of Equity Method Investments [Line Items]

203

PFJ Southeast | Goodwill

PFJ Southeast | Inventories

62

Schedule of Equity Method Investments [Line Items]

Schedule of Equity Method Investments [Line Items]

$ 8

PFJ Southeast | Speedway

Number of travel plazas | Store

41

PFJ Southeast | Pilot Flying J

Schedule of Equity Method Investments [Line Items]

Number of travel plazas | Store

82

[1]	MarkWest’s contribution of assets to Sherwood Midstream and Sherwood Midstream Holdings. See Note 4.

Acquisitions and Investments - Marine Investments (Details) $ in Millions	1 Months Ended	9 Months Ended	12 Months Ended		16 Months Ended
	May 31, 2016 USD ($)	Sep. 30, 2017 Joint_venture vessel	Dec. 31, 2016 vessel	Dec. 31, 2015 vessel	Dec. 31, 2016 USD ($) vessel	May 01, 2016	Sep. 30, 2015
Crowley Coastal Partners
Schedule of Equity Method Investments [Line Items]
Cash paid to acquire equity method investments \| $	$ 48				$ 189
Equity method investments, ownership percentage		50.00%
Crowley Ocean Partners
Schedule of Equity Method Investments [Line Items]
Cash paid to acquire equity method investments \| $					$ 141
Equity method investments, ownership percentage		50.00%				50.00%	50.00%
Number of vessels \| vessel			2	2	4
Crowley Blue Water Partners
Schedule of Equity Method Investments [Line Items]
Equity method investments, ownership percentage		50.00%
Number of vessels \| vessel		3
Crowley Maritime Corporation
Schedule of Equity Method Investments [Line Items]
Number of joint ventures \| Joint_venture		2
Crowley Maritime Corporation \| Crowley Blue Water Partners
Schedule of Equity Method Investments [Line Items]
Percentage of partners interest contributed	100.00%

Acquisitions and Investments - Investment in Pipeline Company (Details) bbl / d in Thousands, $ in Millions		9 Months Ended
	Feb. 15, 2017 USD ($) Quarterly_reporting_period bbl / d	Sep. 30, 2017 USD ($)
Schedule of Equity Method Investments [Line Items]
IDRs forfeited per quarter	$ 1.6
Number of quarters IDRs forfeited \| Quarterly_reporting_period	12
Prorated IDRs forfeited	$ 0.8
MarEn Bakken
Schedule of Equity Method Investments [Line Items]
Cash paid to acquire equity method investments		$ 500.0
Bakken Pipeline System
Schedule of Equity Method Investments [Line Items]
Crude oil throughput \| bbl / d	470
MPLX LP \| MarEn Bakken
Schedule of Equity Method Investments [Line Items]
Cash paid to acquire equity method investments	$ 500.0
Equity method investments, ownership percentage	25.00%
MPLX LP \| Bakken Pipeline System
Schedule of Equity Method Investments [Line Items]
Equity method investments, ownership percentage	9.20%
MPC & Enbridge Energy Partners \| MarEn Bakken
Schedule of Equity Method Investments [Line Items]
Cash paid to acquire equity method investments	$ 2,000.0
MPC & Enbridge Energy Partners \| Bakken Pipeline System
Schedule of Equity Method Investments [Line Items]
Percentage of ownership interest in joint venture acquired	36.75%

Acquisitions and Investments - Formation of Gathering and Processing Joint Venture (Details)
bbl / d in Thousands, $ in Millions

9 Months Ended

Jan. 01, 2017

USD ($)

bbl / d

Sep. 30, 2017

USD ($)

Sep. 30, 2016

USD ($)

Schedule of Equity Method Investments [Line Items]

Schedule of Equity Method Investments [Line Items]

$ 337

^[1]

$ 0

Sherwood Midstream

Sherwood Midstream | MPLX LP

50.00%

Schedule of Equity Method Investments [Line Items]

$ 134

Sherwood Midstream | Antero Midstream Partners L.P.

20

Schedule of Equity Method Investments [Line Items]

Schedule of Equity Method Investments [Line Items]

$ 154

Ohio Fractionation

Capacity | bbl / d

20

Ohio Fractionation | Sherwood Midstream

Schedule of Equity Method Investments [Line Items]

Sherwood Midstream Holdings

$ 126

Schedule of Equity Method Investments [Line Items]

Sherwood Midstream Holdings | Direct Ownership Interest

86.00%

Schedule of Equity Method Investments [Line Items]

Sherwood Midstream Holdings | Indirect Ownership Interest

79.00%

Schedule of Equity Method Investments [Line Items]

Sherwood Midstream Holdings | MPLX LP

10.50%

Schedule of Equity Method Investments [Line Items]

Fair value of assets contributed

$ 203

209

Gain on disposal of assets

$ 2

Sherwood Midstream Holdings | Sherwood Midstream

Schedule of Equity Method Investments [Line Items]

21.00%

$ 44

[1]	MarkWest’s contribution of assets to Sherwood Midstream and Sherwood Midstream Holdings. See Note 4.

Variable Interest Entities (Details) bbl / d in Thousands, $ in Millions	Sep. 30, 2017 USD ($)	Jan. 01, 2017 bbl / d	Dec. 31, 2016 USD ($)
Variable Interest Entity [Line Items]
Equity method investments	$ 4,769		$ 3,827
Crowley Coastal Partners
Variable Interest Entity [Line Items]
VIE, maximum loss exposure, amount	$ 493
Equity method investments, ownership percentage	50.00%
MarkWest Utica EMG
Variable Interest Entity [Line Items]
Equity method investments, ownership percentage	56.00%
Equity method investments	$ 2,200
Ohio Gathering
Variable Interest Entity [Line Items]
Equity method investments, ownership percentage	34.00%
Sherwood Midstream
Variable Interest Entity [Line Items]
Equity method investments, ownership percentage	50.00%
Equity method investments	$ 220
Ohio Fractionation
Variable Interest Entity [Line Items]
Capacity \| bbl / d		20
Sherwood Midstream Holdings
Variable Interest Entity [Line Items]
Equity method investments, ownership percentage	86.00%
Equity method investments	$ 163
Sherwood Midstream Holdings \| Direct Ownership Interest
Variable Interest Entity [Line Items]
Equity method investments, ownership percentage		79.00%
Sherwood Midstream Holdings \| Indirect Ownership Interest
Variable Interest Entity [Line Items]
Equity method investments, ownership percentage		10.50%

Related Party Transactions - Additional Information (Detail) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016	May 01, 2016	Sep. 30, 2015
Related Party Transaction [Line Items]
Due from related parties, noncurrent	$ 1	$ 1
Crowley Blue Water Partners
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	50.00%
Crowley Ocean Partners
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	50.00%		50.00%	50.00%
Explorer
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	25.00%
Illinois Extension Pipeline
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	35.00%
LOCAP
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	59.00%
LOOP
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	51.00%
MarkWest Utica EMG
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	56.00%
Ohio Gathering
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	34.00%
PFJ Southeast
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	29.00%
Sherwood Midstream
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	50.00%
Sherwood Midstream Holdings
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	86.00%
TAAE
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	45.00%
TACE
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	61.00%
TAME
Related Party Transaction [Line Items]
Equity method investments, ownership percentage	67.00%

Related Party Transactions - Sales to Related Parties (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Related Party Transaction [Line Items]
Sales to related parties	$ 157	$ 2	$ 458	$ 5
PFJ Southeast
Related Party Transaction [Line Items]
Sales to related parties	155	0	451	0
Other equity method investees
Related Party Transaction [Line Items]
Sales to related parties	$ 2	$ 2	$ 7	$ 5

Related Party Transactions - Other Income From Related Parties (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Related Party Transaction [Line Items]
Other income from related parties	$ 13	$ 12	$ 39	$ 31
MarkWest Utica EMG
Related Party Transaction [Line Items]
Other income from related parties	5	5	13	12
Ohio Gathering
Related Party Transaction [Line Items]
Other income from related parties	4	5	12	12
Other equity method investees
Related Party Transaction [Line Items]
Other income from related parties	$ 4	$ 2	$ 14	$ 7

Related Party Transactions - Purchases from Related Parties (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Related Party Transaction [Line Items]
Purchases from related parties	$ 148	$ 128	$ 420	$ 359
Crowley Blue Water Partners
Related Party Transaction [Line Items]
Purchases from related parties	16	16	44	22
Crowley Ocean Partners
Related Party Transaction [Line Items]
Purchases from related parties	20	15	59	32
Explorer
Related Party Transaction [Line Items]
Purchases from related parties	7	4	7	12
Illinois Extension Pipeline
Related Party Transaction [Line Items]
Purchases from related parties	26	27	75	82
LOCAP
Related Party Transaction [Line Items]
Purchases from related parties	6	6	17	18
LOOP
Related Party Transaction [Line Items]
Purchases from related parties	14	14	53	42
TAAE
Related Party Transaction [Line Items]
Purchases from related parties	22	9	53	29
TACE
Related Party Transaction [Line Items]
Purchases from related parties	9	10	34	39
TAME
Related Party Transaction [Line Items]
Purchases from related parties	20	23	58	67
Other equity method investees
Related Party Transaction [Line Items]
Purchases from related parties	$ 8	$ 4	$ 20	$ 16

Related Party Transactions - Receivables From Related Parties (Details) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Current receivables from related parties	$ 40	$ 45
MarkWest Utica EMG
Related Party Transaction [Line Items]
Current receivables from related parties	2	2
Ohio Gathering
Related Party Transaction [Line Items]
Current receivables from related parties	2	2
PFJ Southeast
Related Party Transaction [Line Items]
Current receivables from related parties	32	40
Other equity method investees
Related Party Transaction [Line Items]
Current receivables from related parties	$ 4	$ 1

Related Party Transactions - Payables To Related Parties (Detail) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Payables to related parties	$ 64	$ 53
Illinois Extension Pipeline
Related Party Transaction [Line Items]
Payables to related parties	9	9
LOCAP
Related Party Transaction [Line Items]
Payables to related parties	2	2
LOOP
Related Party Transaction [Line Items]
Payables to related parties	5	6
MarkWest Utica EMG
Related Party Transaction [Line Items]
Payables to related parties	30	24
TAAE
Related Party Transaction [Line Items]
Payables to related parties	2	2
TACE
Related Party Transaction [Line Items]
Payables to related parties	1	4
TAME
Related Party Transaction [Line Items]
Payables to related parties	2	4
Other equity method investees
Related Party Transaction [Line Items]
Payables to related parties	$ 13	$ 2

Income Per Common Share - Summary of Earnings Per Common Share (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Basic earnings per share:
Net income attributable to MPC	$ 903	$ 145	$ 1,416	$ 947
Income allocated to participating securities	0	0	1	1
Income available to common stockholders – basic	$ 903	$ 145	$ 1,415	$ 946
Weighted average common shares outstanding (in shares)	504	527	514	528
Basic (in USD per share)	$ 1.79	$ 0.28	$ 2.75	$ 1.79
Diluted earnings per share:
Net income attributable to MPC	$ 903	$ 145	$ 1,416	$ 947
Income allocated to participating securities	0	0	1	1
Income available to common stockholders – diluted	$ 903	$ 145	$ 1,415	$ 946
Weighted average common shares outstanding (in shares)	504	527	514	528
Effect of dilutive securities (in shares)	4	3	4	3
Weighted average common shares, including dilutive effect (in shares)	508	530	518	531
Diluted (in USD per share)	$ 1.77	$ 0.27	$ 2.73	$ 1.78

Income Per Common Share - Anti-dilutive Shares (Details) - shares shares in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Stock Based Compensation Expense [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares issued under stock-based compensation plans	1	3	1	3

Equity - Additional Information (Detail) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended
	Oct. 31, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	May 31, 2017
Stock repurchase program, authorized amount						$ 3,000
Stock repurchase program, remaining authorized repurchase amount		$ 3,940		$ 3,940
Number of shares repurchased		8,000,000	1,000,000	31,000,000	4,000,000
Cash paid for shares repurchased		$ 452	$ 51	$ 1,622	$ 177
Scenario, Forecast
Number of shares repurchased	985,400
Cash paid for shares repurchased	$ 55

Equity - Share Repurchases (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Equity [Abstract]
Number of shares repurchased	8	1	31	4
Cash paid for shares repurchased	$ 452	$ 51	$ 1,622	$ 177
Effective average cost per delivered share	$ 53.85	$ 42.76	$ 52.16	$ 41.14

Segment Information - Additional Information (Detail)	9 Months Ended
Segment Information - Additional Information (Detail)	Sep. 30, 2017 Segment refinery
Segment Reporting [Abstract]
Number of reportable segments \| Segment	3
Number of refineries \| refinery	7

Segment Information - Income From Operations Attributable To Operating Segments (Detail) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2017

Sep. 30, 2016

Sep. 30, 2017

Sep. 30, 2016

$ 19,053

$ 16,616

$ 53,220

$ 46,179

157

2

458

5

1,576

435

2,850

1,825

84

(208)

224

(236)

517

507

1,574

1,497

^[1]

791

761

2,900

2,232

0

(370)

MarEn Bakken

Intersegment Eliminations

500

^[2]

3,274

3,145

9,381

8,785

22,484

19,763

63,059

54,969

1,661

771

3,168

2,512

83

59

^[3]

203

120

^[3]

^[3]

503

493

1,530

1,452

^[4]

759

732

2,808

^[5]

2,126

53

69

730

^[6]

383

^[6]

Refining & Marketing

13,573

11,284

37,485

31,192

155

2

452

5

Refining & Marketing | Intersegment Eliminations

345

Refining & Marketing | Operating Segments

2,904

2,798

8,302

7,872

16,632

14,084

46,239

39,069

1,097

252

1,589

^[7]

1,191

^[8]

6

8

10

266

267

805

801

198

251

570

756

Speedway

4,895

4,848

14,070

13,663

2

0

6

0

Speedway | Intersegment Eliminations

25

Speedway | Operating Segments

1

3

2

4,898

4,849

14,079

13,665

209

583

569

^[8]

20

0

54

0

68

71

197

203

108

71

221

191

Midstream

585

484

1,665

1,324

Midstream | Ozark Pipeline

0

Midstream | Intersegment Eliminations

220

Midstream | Operating Segments

369

346

1,076

911

954

830

2,741

2,235

^[9]

355

310

996

^[7]

752

57

51

139

110

169

155

528

448

453

410

2,017

^[5]

1,179

Reportable Segment

Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]

$ 19,053

$ 16,616

$ 53,220

$ 46,179

[1]	Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates.
[2]	Management believes intersegment transactions were conducted under terms comparable to those with unaffiliated parties
[3]	Differences between segment totals and MPC totals represent amounts related to unallocated items and are included in “Items not allocated to segments” in the reconciliation below.
[4]	Capital expenditures include changes in capital accruals, acquisitions (including any goodwill) and investments in affiliates.
[5]	The Midstream segment includes $220 million for the acquisition of the Ozark pipeline and an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system for the nine months ended September 30, 2017.
[6]	The nine months ended September 30, 2017 includes an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system. The nine months ended September 30, 2016 includes an adjustment of $143 million to the fair value of equity method investments acquired in connection with the MarkWest Merger
[7]	We revised our operating segment presentation in the first quarter of 2017 in connection with the contribution of certain terminal, pipeline and storage assets to MPLX. The operating results for these assets, which were previously included in the Refining & Marketing segment, are now included in the Midstream segment. Comparable prior period information has been recast to reflect our revised presentation. The results for the pipeline and storage assets were recast effective January 1, 2015, and the results for the terminal assets were recast effective April 1, 2016. Prior to these dates, these assets were not considered businesses and, therefore, there are no financial results from which to recast segment results.
[8]	The Refining & Marketing and Speedway segments include inventory LCM benefits of $345 million and $25 million, respectively, for the nine months ended September 30, 2016
[9]	Corporate overhead expenses attributable to MPLX are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.

Segment Information - Reconciliation Of Segment Income From Operations To Income Before Income Taxes (Detail) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2017

Sep. 30, 2016

Sep. 30, 2017

Sep. 30, 2016

$ 1,576

$ 435

$ 2,850

$ 1,825

Net interest and other financial income (costs)

0

130

157

141

465

420

Income before income taxes

1,419

294

2,385

1,405

Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]

1,661

771

3,168

2,512

Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]

Segment Reconciling Items

^[1]

(86)

(65)

(251)

^[2]

(194)

Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]

Pension settlement expenses

(1)

(4)

(2)

(7)

Litigation

0

(86)

^[3]

0

Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures [Line Items]

^[4]

$ 2

$ (267)

$ 21

$ (486)

[1]	Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets, except for corporate overhead expenses attributable to MPLX, which are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.
[2]	We revised our operating segment presentation in the first quarter of 2017 in connection with the contribution of certain terminal, pipeline and storage assets to MPLX. The operating results for these assets, which were previously included in the Refining & Marketing segment, are now included in the Midstream segment. Comparable prior period information has been recast to reflect our revised presentation. The results for the pipeline and storage assets were recast effective January 1, 2015, and the results for the terminal assets were recast effective April 1, 2016. Prior to these dates, these assets were not considered businesses and, therefore, there are no financial results from which to recast segment results.
[3]	See Note 21 for further information on litigation matters.
[4]	2017 includes MPC’s share of gains related to the sale of assets remaining from the Sandpiper pipeline project. 2016 relates to impairments of goodwill and equity method investments.

Segment Information - Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures (Detail) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2017

Sep. 30, 2016

Sep. 30, 2017

Sep. 30, 2016

Plus items not allocated to segments:

^[1]

$ 791

$ 761

$ 2,900

$ 2,232

Capital expenditures

^[2]

738

692

2,170

1,849

MarkWest | Adjustments

Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures [Line Items]

Less: Investments in equity method investees

143

MarEn Bakken

Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures [Line Items]

Less: Investments in equity method investees

500

Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures [Line Items]

Less: Investments in equity method investees

^[3]

759

732

2,808

^[4]

2,126

53

69

730

^[5]

383

^[5]

Reconciliation Of Segment Capital Expenditures And Investments To Total Capital Expenditures [Line Items]

Plus items not allocated to segments:

^[6]

32

29

92

106

19

14

53

59

Capitalized interest

$ 13

$ 15

$ 39

$ 47

[1]	Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates.
[2]	Capital expenditures include changes in capital accruals. See Note 17 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.
[3]	Capital expenditures include changes in capital accruals, acquisitions (including any goodwill) and investments in affiliates.
[4]	The Midstream segment includes $220 million for the acquisition of the Ozark pipeline and an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system for the nine months ended September 30, 2017.
[5]	The nine months ended September 30, 2017 includes an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system. The nine months ended September 30, 2016 includes an adjustment of $143 million to the fair value of equity method investments acquired in connection with the MarkWest Merger
[6]	Includes capitalized interest of $13 million and $15 million for the three months ended September 30, 2017 and 2016, respectively, and $39 million and $47 million for the nine months ended September 30, 2017 and 2016, respectively.

Other Items - Net Interest And Other Financial Income (Costs) (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Other Income and Expenses [Abstract]
Interest income	$ 7	$ 3	$ 16	$ 5
Interest expense	(172)	(153)	(508)	(455)
Interest capitalized	14	15	47	47
Other financial costs	(6)	(6)	(20)	(17)
Net interest and other financial income (costs)	$ (157)	$ (141)	$ (465)	$ (420)

Income Taxes - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Income Tax Disclosure [Abstract]
Combined federal, state and foreign income tax rate	29.00%	26.00%	30.00%	34.00%
Statutory rate applied to income before income taxes		35.00%	35.00%	35.00%
Unrecognized benefits	$ 19		$ 19

Inventories - Summary Of Inventories (Detail) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
Inventory Disclosure [Abstract]
Crude oil and refinery feedstocks	$ 2,147	$ 2,208
Refined products	2,706	2,810
Materials and supplies	486	485
Merchandise	154	153
Total	$ 5,493	$ 5,656

Inventories - Additional Information (Detail) $ in Millions	9 Months Ended
Inventories - Additional Information (Detail) $ in Millions	Sep. 30, 2017 USD ($)
Inventory Disclosure [Abstract]
Impact on income as a result of LIFO liquidations	$ 0

Property, Plant And Equipment - Summary Of Property, Plant And Equipment (Detail) - USD ($)
$ in Millions

Sep. 30, 2017

Dec. 31, 2016

Less accumulated depreciation

$ 39,718

$ 38,006

13,682

12,241

Net property, plant and equipment

26,036

25,765

Operating Segments | Refining & Marketing

Operating Segments | Speedway

19,174

18,590

^[1]

Operating Segments | Midstream

5,233

5,078

14,489

13,521

^[1]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

$ 822

$ 817

[1]	Prior period balances have been recast in connection with the March 1, 2017 contribution of assets to MPLX. See Note 1 for additional information.

Fair Value Measurements - Assets and Liabilities Accounted for at Fair Value on Recurring Basis (Detail) - USD ($)
$ in Millions

Sep. 30, 2017

Dec. 31, 2016

Cash collateral netted with derivative liabilities

$ 39

$ 24

Contingent consideration, current

130

Embedded derivatives in commodity contracts

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Embedded derivatives, current

15

13

Fair Value, Measurements, Recurring

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Commodity derivative instruments, assets - netting and collateral

(257)

(688)

Commodity derivative instruments, assets - collateral pledged not offset

22

126

3

2

Commodity derivative instruments, liabilities - netting and collateral

3

2

(296)

(712)

Commodity derivative instruments, liabilities - collateral pledged not offset

0

130

Fair Value, Measurements, Recurring | Commodity derivatives

57

190

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Commodity derivative instruments, assets - netting and collateral

^[1]

(257)

(688)

Commodity derivative instruments, assets - net carrying value on balance sheet

^[2]

0

Commodity derivative instruments, assets - collateral pledged not offset

22

126

Commodity derivative instruments, liabilities - netting and collateral

^[1]

(296)

(712)

Commodity derivative instruments, liabilities - net carrying value on balance sheet

^[2]

5

6

Commodity derivative instruments, liabilities - collateral pledged not offset

0

Fair Value, Measurements, Recurring | Embedded derivatives in commodity contracts

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Commodity derivative instruments, liabilities - netting and collateral

0

Commodity derivative instruments, liabilities - net carrying value on balance sheet

^[2]

52

54

Commodity derivative instruments, liabilities - collateral pledged not offset

0

Fair Value, Measurements, Recurring | Level 1

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

3

2

260

690

0

Fair Value, Measurements, Recurring | Level 1 | Commodity derivatives

296

712

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Commodity derivative instruments, assets - gross

257

688

Commodity derivative instruments, liabilities - gross

296

712

Fair Value, Measurements, Recurring | Level 1 | Embedded derivatives in commodity contracts

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Commodity derivative instruments, liabilities - gross

0

Fair Value, Measurements, Recurring | Level 2

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

0

0

0

Fair Value, Measurements, Recurring | Level 2 | Commodity derivatives

0

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Commodity derivative instruments, assets - gross

0

Commodity derivative instruments, liabilities - gross

0

Fair Value, Measurements, Recurring | Level 2 | Embedded derivatives in commodity contracts

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Commodity derivative instruments, liabilities - gross

0

Fair Value, Measurements, Recurring | Level 3

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

0

0

^[3]

130

Fair Value, Measurements, Recurring | Level 3 | Commodity derivatives

57

190

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Commodity derivative instruments, assets - gross

0

Commodity derivative instruments, liabilities - gross

5

^[4]

6

Fair Value, Measurements, Recurring | Level 3 | Embedded derivatives in commodity contracts

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Commodity derivative instruments, liabilities - gross

^[4]

$ 52

$ 54

[1]	Represents the impact of netting assets, liabilities and cash collateral when a legal right of offset exists. As of September 30, 2017, cash collateral of $39 million was netted with the mark-to-market derivative liabilities. As of December 31, 2016, $24 million was netted with mark-to-market derivative liabilities.
[2]	We have no derivative contracts that are subject to master netting arrangements reflected gross on the balance sheet.
[3]	Includes $130 million classified as current at December 31, 2016.
[4]	Level 3 includes $15 million and $13 million classified as current at September 30, 2017 and December 31, 2016, respectively.

Fair Value Measurements - Recurring Narrative (Detail) - USD ($)		9 Months Ended
	Apr. 12, 2017	Sep. 30, 2017	Sep. 30, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration payment, financing activities		$ 89,000,000	$ 164,000,000
Galveston Bay Refinery and Related Assets
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration payment	$ 131,000,000
Commodity derivatives \| Level 3 \| Ethanol prices \| Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Forward commodity price		0.27
Commodity derivatives \| Level 3 \| Ethanol prices \| Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Forward commodity price		$ 1.22
Embedded derivatives in commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Embedded derivative renewal term		5 years
Embedded derivatives in commodity contracts \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Probability of renewal first term		50.00%
Probability of renewal second term		75.00%

Fair Value Measurements - Reconciliation of Net Beginning and Ending Balances Recorded for Net Assets and Liabilities Classified as Level 3 (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 41	$ 171	$ 190	$ 342
Contingent consideration payment	0	0	(131)	(200)
Unrealized and realized losses included in net income	22	6	8	33
Settlements of derivative instruments	(6)	(1)	(10)	1
Ending balance	$ 57	$ 176	$ 57	$ 176

Fair Value Measurements - Losses Included in Earnings Relating to Assets Still Held at End of Period (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets still held at the end of period:	$ 17	$ 6	$ 9	$ 30
Derivative
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets still held at the end of period:	17	4	8	19
Contingent Consideration
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets still held at the end of period:	$ 0	$ 2	$ 1	$ 11

Fair Value Measurements - Financial Instruments at Fair Value, Excluding Derivative Financial Instruments and Contingent Consideration (Detail) - USD ($)
$ in Millions

Sep. 30, 2017

Dec. 31, 2016

Fair Value

Financial assets:

Investments

$ 25

Deferred credits and other liabilities

25

21

Total financial assets

50

46

Financial liabilities:

Long-term debt

^[1]

13,690

10,892

121

Total financial liabilities

13,811

11,013

Carrying Value

Financial assets:

Investments

2

Deferred credits and other liabilities

25

21

Total financial assets

27

23

Financial liabilities:

Long-term debt

^[1]

12,544

10,297

107

109

Total financial liabilities

$ 12,651

$ 10,406

[1]	Excludes capital leases and debt issuance costs; however, includes amount classified as debt due within one year.

Derivatives - Classification of Gross Fair Values of Derivative Instruments, Excluding Cash Collateral (Detail) - Commodity derivatives - USD ($)
$ in Millions

Sep. 30, 2017

Dec. 31, 2016

Other current assets

Derivatives, Fair Value [Line Items]

Asset

$ 257

$ 688

Liability

296

712

Other current liabilities(a)

Derivatives, Fair Value [Line Items]

Asset

0

Liability

^[1]

15

13

Deferred credits and other liabilities

Derivatives, Fair Value [Line Items]

Asset

0

Liability

^[1]

$ 42

$ 47

[1]	Includes embedded derivatives.

Derivatives - Open Commodity Derivative Contracts - Crude Oil (Details) - Crude Oil - Exchange Traded
bbl in Thousands

3 Months Ended

Sep. 30, 2017

bbl

Percentage of derivative contracts expiring in the period

94.00%

Derivative contract expiration date

Dec. 31, 2017

Long

Notional contracts (in thousands of Total Barrels)

33,043

^[1]

Short

Notional contracts (in thousands of Total Barrels)

34,428

^[1]

[1]	of the exchange-traded contracts expire in the fourth quarter of 2017.

Derivatives - Open Commodity Derivative Contracts - Refined Products (Detail) - Refined Products
gal in Thousands

3 Months Ended

Sep. 30, 2017

gal

Exchange Traded

Percentage of derivative contracts expiring in the period

100.00%

Derivative contract expiration date

Dec. 31, 2017

Exchange Traded | Long

Notional contracts (in thousands of Total Gallons)

316,764

^[1]

Exchange Traded | Short

Notional contracts (in thousands of Total Gallons)

227,388

^[1]

Over the Counter | Short

Notional contracts (in thousands of Total Gallons)

33,388

[1]	of the exchange-traded contracts expire in the fourth quarter of 2017.

Derivatives - Effect of Commodity Derivative Instruments in Statements of Income (Detail) - Commodity derivatives - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss)	$ (9)	$ (23)	$ (22)	$ (95)
Sales and other operating revenues
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss)	(10)	(3)	8	(4)
Cost of revenues
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss)	$ 1	$ (20)	$ (30)	$ (91)

Debt - Outstanding Borrowings (Detail) - USD ($)
$ in Millions

9 Months Ended

Sep. 30, 2017

Feb. 10, 2017

Dec. 31, 2016

Unamortized debt issuance costs

Commercial paper

$ 0

Total

13,269

11,069

(61)

(44)

Unamortized discount

^[1]

(426)

(453)

Amounts due within one year

(29)

(28)

Total long-term debt due after one year

12,753

10,544

MPLX LP

Amounts due within one year

(1)

Total long-term debt due after one year

6,848

4,422

Senior Notes | MPLX LP | MarkWest

Capital Lease Obligations | Subsidiaries

63

Unamortized discount

(386)

(420)

Capital lease obligations

$ 299

319

Debt instrument maturity year, start

Jan. 01, 2017

Debt instrument maturity year, end

Dec. 31, 2028

364-day bank revolving credit facility due July 2018 | Line of Credit

$ 0

0

Trade receivables securitization facility due July 2019

Jul. 20, 2018

Trade receivables securitization facility due July 2019 | Secured Debt

$ 0

Trade receivables securitization facility due July 2019 | Secured Debt | Subsidiaries

$ 0

0

Bank revolving credit facility due 2022 | Line of Credit

Jul. 19, 2019

$ 0

0

Term loan agreement due 2019 | Unsecured Debt

Jul. 21, 2022

$ 0

200

Senior notes, 2.700% due December 2018 | Senior Notes

Sep. 24, 2019

$ 600

600

Dec. 14, 2018

Senior notes, 3.400% due December 2020 | Senior Notes

2.70%

$ 650

650

Dec. 15, 2020

Senior notes, 5.125% due March 2021 | Senior Notes

3.40%

$ 1,000

1,000

Mar. 01, 2021

Senior notes, 3.625%, due September 2024 | Senior Notes

5.125%

$ 750

750

Sep. 15, 2024

Senior notes, 6.500%, due March 2041 | Senior Notes

3.625%

$ 1,250

1,250

Mar. 01, 2041

Senior notes, 4.750%, due September 2044 | Senior Notes

6.50%

$ 800

800

Sep. 15, 2044

Senior notes, 5.850% due December 2045 | Senior Notes

4.75%

$ 250

250

Dec. 15, 2045

Senior notes, 5.000%, due September 2054 | Senior Notes

5.85%

$ 400

400

Sep. 15, 2054

MPLX term loan facility due 2019 | Unsecured Debt | MPLX LP

5.00%

$ 0

250

MPLX bank revolving credit facility due 2022 | Line of Credit | MPLX LP

Nov. 20, 2019

$ 420

0

MPLX senior notes, 5.500%, due February 2023 | Senior Notes | MPLX LP

Jul. 21, 2022

$ 710

710

Feb. 15, 2023

MPLX senior notes, 5.500%, due February 2023 | Senior Notes | MPLX LP | MarkWest

5.50%

Feb. 15, 2023

MPLX senior notes, 4.500%, due July 2023 | Senior Notes | MPLX LP

5.50%

$ 989

989

Jul. 15, 2023

MPLX senior notes, 4.500%, due July 2023 | Senior Notes | MPLX LP | MarkWest

4.50%

Jul. 15, 2023

MPLX senior notes, 4.875%, due December 2024 | Senior Notes | MPLX LP

4.50%

$ 1,149

1,149

Dec. 01, 2024

MPLX senior notes, 4.875%, due December 2024 | Senior Notes | MPLX LP | MarkWest

4.875%

Dec. 01, 2024

MPLX senior notes, 4.000%, due February 2025 | Senior Notes | MPLX LP

4.875%

$ 500

500

Feb. 15, 2025

MPLX senior notes, 4.875%, due June 2025 | Senior Notes | MPLX LP

4.00%

$ 1,189

1,189

Jun. 01, 2025

MPLX senior notes, 4.875%, due June 2025 | Senior Notes | MPLX LP | MarkWest

4.875%

Jun. 01, 2025

MPLX senior notes, 4.125%, due March 2027 | Senior Notes | MPLX LP

4.875%

$ 1,250

0

Mar. 01, 2027

MPLX senior notes, 5.200%, due March 2047 | Senior Notes | MPLX LP

4.125%

$ 1,000

$ 0

Mar. 01, 2047

Net cash provided by operating activities included:

5.20%

[1]	Includes $386 million and $420 million of unamortized discount as of September 30, 2017 and December 31, 2016, respectively, related to the difference between the fair value and the principal amount of assumed MarkWest debt.

Debt - Narrative (Details) - USD ($) $ in Millions	9 Months Ended
Debt - Narrative (Details) - USD ($) $ in Millions	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Debt Instrument [Line Items]
Commercial paper – issued	$ 300	$ 1,063
Commercial paper - repayments	300	$ 1,063
Commercial paper	0		$ 0
Trade receivables securitization facility due July 2019
Debt Instrument [Line Items]
Borrowings	0
Repayments	0
Long-term debt, gross	$ 0

Debt - MPC Bank Revolving Credit Facilities (Details) - USD ($) $ in Millions	Jul. 21, 2017	Jul. 20, 2016	Sep. 30, 2017	Dec. 31, 2016
Bank revolving credit facility due 2020
Debt Instrument [Line Items]
Maximum borrowing capacity		$ 2,500
Debt instrument, term		4 years
Bank revolving credit facility due 2020 \| Letter of Credit
Debt Instrument [Line Items]
Long-term line of credit			$ 0
Bank revolving credit facility due 2020 \| Line of Credit
Debt Instrument [Line Items]
Long-term debt, gross			0
364-day bank revolving credit facility
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 1,000	$ 1,000
Debt instrument, term	364 days	364 days
364-day bank revolving credit facility \| Line of Credit
Debt Instrument [Line Items]
Long-term debt, gross			0	$ 0
Bank revolving credit facility due 2022
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 2,500
Debt instrument, term	5 years
Bank revolving credit facility due 2022 \| Line of Credit
Debt Instrument [Line Items]
Long-term debt, gross			$ 0	$ 0

Debt - MPC Term Loan Agreement (Details) $ in Millions	Mar. 31, 2017 USD ($)
Term loan agreement due 2019
Debt Instrument [Line Items]
Repayments of long-term debt	$ 200

Debt - MPLX Credit Agreement (Details) - MPLX LP - USD ($) $ in Millions				9 Months Ended
	Jul. 21, 2017	Jul. 19, 2017	Oct. 27, 2015	Sep. 30, 2017	Dec. 31, 2016
MPLX bank revolving credit facility due 2022
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 2,250		$ 2,000
Debt instrument, term	5 years		5 years
Borrowings				$ 420
Interest rate during period				2.70%
Repayments				$ 0
Remaining borrowing capacity				1,830
MPLX bank revolving credit facility due 2022 \| Letter of Credit
Debt Instrument [Line Items]
Long-term line of credit				3
MPLX bank revolving credit facility due 2022 \| Line of Credit
Debt Instrument [Line Items]
Long-term debt, gross				$ 420	$ 0
MPLX term loan facility due 2019
Debt Instrument [Line Items]
Repayments of long-term debt		$ 250

Debt - MPLX Senior Notes (Details) - MPLX LP - USD ($) $ in Millions			9 Months Ended
	Sep. 01, 2017	Mar. 01, 2017	Sep. 30, 2017	Feb. 10, 2017	Dec. 31, 2016
Cash and Cash Equivalents
Debt Instrument [Line Items]
Payments to acquire business, gross	$ 420	$ 1,500
Senior Notes
Debt Instrument [Line Items]
Net proceeds			$ 2,220
Senior Notes \| MPLX senior notes, 4.125%, due March 2027
Debt Instrument [Line Items]
Long-term debt, gross			$ 1,250	$ 1,250	$ 0
Debt instrument, interest rate			4.125%	4.125%
Senior Notes \| MPLX senior notes, 5.200%, due March 2047
Debt Instrument [Line Items]
Long-term debt, gross			$ 1,000	$ 1,000	$ 0
Debt instrument, interest rate			5.20%	5.20%

Supplemental Cash Flow Information - Summary of Supplemental Cash Flow Information (Detail) - USD ($)
$ in Millions

9 Months Ended

Sep. 30, 2017

Sep. 30, 2016

Interest paid (net of amounts capitalized)

$ 446

$ 400

Net income taxes paid to (refunded from) taxing authorities

383

28

Non-cash investing and financing activities:

Supplemental Cash Flow Elements [Abstract]

$ 337

^[1]

$ 0

[1]	MarkWest’s contribution of assets to Sherwood Midstream and Sherwood Midstream Holdings. See Note 4.

Supplemental Cash Flow Information - Reconciliation of Additions to Property, Plant and Equipment to Total Capital Expenditures (Detail) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2017

Sep. 30, 2016

Sep. 30, 2017

Sep. 30, 2016

Additions to property, plant and equipment per consolidated statements of cash flows

$ 1,928

$ 2,147

Asset retirement expenditures

1

4

Decrease in capital accruals

(9)

(169)

Total capital expenditures before acquisitions

1,920

1,982

Acquisitions

^[1]

250

(133)

Capital expenditures

^[2]

$ 738

$ 692

$ 2,170

$ 1,849

[1]	The nine months ended September 30, 2017 reflects primarily the acquisition of the Ozark pipeline. The nine months ended September 30, 2016 reflects adjustments to the fair values of the property, plant and equipment, intangibles and goodwill acquired in connection with the MarkWest Merger.
[2]	Capital expenditures include changes in capital accruals. See Note 17 for a reconciliation of total capital expenditures to additions to property, plant and equipment as reported in the consolidated statements of cash flows.

Accumulated Other Comprehensive Loss - Changes in Accumulated Other Comprehensive Loss by Component (Detail) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2017

Sep. 30, 2016

Sep. 30, 2017

Sep. 30, 2016

Accumulated Other Comprehensive Income (Loss) [Line Items]

$ (234)

$ (318)

Amounts reclassified from accumulated other comprehensive loss:

(2)

(7)

Amortization - prior service credit

(31)

(37)

Amortization - actuarial loss

26

29

Amortization - settlement loss

2

7

(2)

(1)

2

0

$ (3)

$ (6)

(5)

(9)

Accumulated Defined Benefit Plans Adjustment | Pension Benefits

(239)

(327)

(239)

(327)

Accumulated Other Comprehensive Income (Loss) [Line Items]

(233)

(255)

Amounts reclassified from accumulated other comprehensive loss:

(2)

(8)

Amortization - prior service credit

^[1]

(29)

(35)

Amortization - actuarial loss

^[1]

27

28

Amortization - settlement loss

^[1]

2

7

0

(2)

(8)

Accumulated Defined Benefit Plans Adjustment | Other Benefits

(235)

(263)

(235)

(263)

Accumulated Other Comprehensive Income (Loss) [Line Items]

(7)

(70)

Amounts reclassified from accumulated other comprehensive loss:

0

1

Amortization - prior service credit

^[1]

(2)

Amortization - actuarial loss

^[1]

(1)

1

Amortization - settlement loss

0

1

0

(2)

0

Accumulated Other Comprehensive Income (Loss) [Line Items]

(9)

(70)

(9)

(70)

Gain on Cash Flow Hedge

4

Amounts reclassified from accumulated other comprehensive loss:

0

0

0

Accumulated Other Comprehensive Income (Loss) [Line Items]

4

Workers Compensation

2

3

Amounts reclassified from accumulated other comprehensive loss:

0

^[2]

(2)

(1)

1

0

(1)

$ 1

$ 2

$ 1

$ 2

[1]	These accumulated other comprehensive loss components are included in the computation of net periodic benefit cost. See Note 19.
[2]	This amount was reclassified out of accumulated other comprehensive loss and is included in selling, general and administrative on the consolidated statements of income.

Defined Benefit Pension and Other Postretirement Plans - Components of Net Periodic Benefit Costs (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Pension Benefits
Components of net periodic benefit cost:
Service cost	$ 33	$ 29	$ 99	$ 86
Interest cost	19	18	56	55
Expected return on plan assets	(25)	(24)	(75)	(73)
Amortization – prior service credit	(10)	(12)	(29)	(35)
Amortization – actuarial loss (gain)	9	10	27	28
Amortization - settlement loss	1	4	2	7
Net periodic benefit cost	27	25	80	68
Other Benefits
Components of net periodic benefit cost:
Service cost	6	8	19	24
Interest cost	8	9	23	26
Expected return on plan assets	0	0	0	0
Amortization – prior service credit	0	(1)	(2)	(2)
Amortization – actuarial loss (gain)	0	0	(1)	1
Amortization - settlement loss	0	0	0	0
Net periodic benefit cost	$ 14	$ 16	$ 39	$ 49

Defined Benefit Pension and Other Postretirement Plans - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2017 USD ($)
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Employer contributions	$ 120
Other Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Benefits paid	7
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Benefits paid	$ 23

Stock-Based Compensation Plans - Summary of Stock Option Award Activity (Detail) - Stock Options	9 Months Ended
	Sep. 30, 2017 $ / shares shares
Number of Shares
Outstanding, beginning balance \| shares	9,531,440
Granted \| shares	1,214,112
Exercised \| shares	(1,356,217)
Forfeited, canceled or expired \| shares	(78,386)
Outstanding, ending balance \| shares	9,310,949
Weighted Average Exercise Price
Outstanding, beginning balance (in USD per share) \| $ / shares	$ 28.93
Granted (in USD per share) \| $ / shares	50.57
Exercised (in USD per share) \| $ / shares	21.89
Forfeited, canceled or expired (in USD per share) \| $ / shares	41.97
Outstanding, ending balance (in USD per share) \| $ / shares	$ 32.66

Stock-Based Compensation Plans - Narrative (Detail)	9 Months Ended
Stock-Based Compensation Plans - Narrative (Detail)	Sep. 30, 2017 $ / shares
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant date fair value (in USD per share)	$ 13.42
Performance Unit Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in USD per share)	$ 0.92

Stock-Based Compensation Plans - Summary of Restricted Stock Award Activity (Detail)	9 Months Ended
	Sep. 30, 2017 $ / shares shares
Restricted Stock
Number of Shares
Outstanding, beginning balance \| shares	1,250,343
Granted \| shares	574,602
RS’s Vested/RSU’s Issued \| shares	(522,454)
Forfeited \| shares	(83,806)
Outstanding, ending balance \| shares	1,218,685
Weighted Average Grant Date Fair Value
Outstanding, beginning balance (in USD per share) \| $ / shares	$ 41.51
Granted (in USD per share) \| $ / shares	50.20
RS's Vested/RSU's Issued (in USD per share) \| $ / shares	42.48
Forfeited (in USD per share) \| $ / shares	44.29
Outstanding, ending balance (in USD per share) \| $ / shares	$ 45.00
Restricted Stock Units
Number of Shares
Outstanding, beginning balance \| shares	361,117
Granted \| shares	28,573
RS’s Vested/RSU’s Issued \| shares	(79,635)
Forfeited \| shares	(13,750)
Outstanding, ending balance \| shares	296,305
Weighted Average Grant Date Fair Value
Outstanding, beginning balance (in USD per share) \| $ / shares	$ 28.26
Granted (in USD per share) \| $ / shares	51.94
RS's Vested/RSU's Issued (in USD per share) \| $ / shares	24.54
Forfeited (in USD per share) \| $ / shares	50.20
Outstanding, ending balance (in USD per share) \| $ / shares	$ 30.52

Stock-Based Compensation Plans - Summary of Performance Unit Awards (Detail) - Performance Unit Awards	9 Months Ended
	Sep. 30, 2017 $ / shares shares
Number of Units
Outstanding, beginning balance \| shares	6,255,178
Granted \| shares	2,584,750
Exercised \| shares	(1,854,728)
Canceled \| shares	(99,658)
Outstanding, ending balance \| shares	6,885,542
Weighted Average Grant Date Fair Value
Outstanding, beginning balance (in USD per share) \| $ / shares	$ 0.78
Granted (in USD per share) \| $ / shares	0.92
Exercised (in USD per share) \| $ / shares	0.85
Canceled (in USD per share) \| $ / shares	0.78
Outstanding, ending balance (in USD per share) \| $ / shares	$ 0.81

Commitments and Contingencies (Detail)	9 Months Ended
Commitments and Contingencies (Detail)	Sep. 30, 2017
Pending Litigation
Loss Contingencies [Line Items]
Loss contingency, inestimable loss	For matters for which we have not recorded a liability, we are unable to estimate a range of possible loss because the issues involved have not been fully developed through pleadings, discovery or court proceedings.

Commitments and Contingencies - Environmental Matters (Details) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Accrued liabilities for remediation	$ 117	$ 132
Receivables for recoverable costs	$ 45	$ 58

Commitments and Contingencies - MarkWest Environmental Proceeding (Details) - Pending Litigation - MarkWest Liberty Midstream Pipeline Launcher/Receiver Site [Member] $ in Millions	9 Months Ended
	Sep. 30, 2017 USD ($)
Cash
Loss Contingencies [Line Items]
Damages sought	$ 1.2
Other Liabilities
Loss Contingencies [Line Items]
Damages sought	1.6
Scenario, Previously Reported [Member] \| Cash
Loss Contingencies [Line Items]
Damages sought	2.4
Scenario, Previously Reported [Member] \| Other Liabilities
Loss Contingencies [Line Items]
Damages sought	$ 3.6

Commitments and Contingencies - Other Lawsuits (Details) $ in Millions	9 Months Ended
	Sep. 30, 2017 USD ($) lawsuit
Galveston Bay Refinery Fire
Loss Contingencies [Line Items]
Number of lawsuits \| lawsuit	4
Litigation settlement expense	$ 86
Emergency Pricing And Consumer Protection Laws \| Pending Litigation
Loss Contingencies [Line Items]
Plaintiff	Commonwealth of Kentucky
Damages sought	$ 89
Loss contingency, period of occurrence	during September and October 2005

Commitments and Contingencies - Guarantees (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2017	May 01, 2016	Sep. 30, 2015
Indemnification Agreement \| Marathon Oil Companies
Loss Contingencies [Line Items]
Guarantee obligation current carrying value	$ 2
Other Guarantees
Loss Contingencies [Line Items]
Maximum potential undiscounted payments	93
Guarantee obligations maximum exposure per event	50
LOOP and LOCAP LLC \| Guarantee of Indebtedness of Others \| Financial Guarantee
Loss Contingencies [Line Items]
Maximum potential undiscounted payments	$ 160
Line of credit facility, expiration date	Dec. 31, 2037
Centennial \| Guarantee of Indebtedness of Others \| Financial Guarantee
Loss Contingencies [Line Items]
Maximum potential undiscounted payments	$ 22
Centennial \| Master Shelf Agreement [Member] \| Financial Guarantee
Loss Contingencies [Line Items]
Line of credit facility, expiration date	Dec. 31, 2024
Crowley Ocean Partners
Loss Contingencies [Line Items]
Equity method investments, ownership percentage	50.00%	50.00%	50.00%
Crowley Ocean Partners \| Guarantee of Indebtedness of Others \| Financial Guarantee
Loss Contingencies [Line Items]
Maximum potential undiscounted payments	$ 163
Crowley Ocean Partners \| Guarantee of Indebtedness of Others \| Financial Guarantee \| Crowley Term Loan
Loss Contingencies [Line Items]
Maximum borrowing capacity	$ 325
Crowley Blue Water Partners
Loss Contingencies [Line Items]
Equity method investments, ownership percentage	50.00%
Crowley Blue Water Partners \| Guarantee of Indebtedness of Others \| Financial Guarantee
Loss Contingencies [Line Items]
Maximum potential undiscounted payments	$ 139

Commitments and Contingencies - Contractual Commitments and Contingencies (Details) $ in Millions	9 Months Ended
	Sep. 30, 2017 USD ($)
Commitments and Contingencies Disclosure [Abstract]
Contractual commitments to acquire property, plant and equipment and advance funds to equity method investees	$ 694

Supplementary Statistics - Supplementary Statistics (Detail) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2017

Sep. 30, 2016

Sep. 30, 2017

Sep. 30, 2016

$ 1,576

$ 435

$ 2,850

$ 1,825

0

130

^[1]

791

761

2,900

2,232

0

(370)

MarEn Bakken

500

Refining & Marketing

345

Speedway

Midstream | Ozark Pipeline

25

220

1,661

771

3,168

2,512

^[2]

759

732

2,808

^[3]

2,126

Operating Segments | Refining & Marketing

53

69

730

^[4]

383

^[4]

1,097

252

1,589

^[5]

1,191

^[6]

Operating Segments | Speedway

198

251

570

756

209

583

569

^[6]

Operating Segments | Midstream

108

71

221

191

^[7]

355

310

996

^[5]

752

453

410

2,017

^[3]

1,179

^[8]

(86)

(65)

(251)

^[5]

(194)

Segment Reconciling Items

^[9]

32

29

92

106

Capitalized interest

13

15

39

47

Pension settlement expenses

(1)

(4)

(2)

(7)

Litigation

0

(86)

^[10]

0

MPC Consolidated Refined Product Sales Volumes (thousands of barrels per day)

^[11]

$ 2

$ (267)

$ 21

$ (486)

[1]	Capital expenditures include changes in capital accruals, acquisitions and investments in affiliates.
[2]	Capital expenditures include changes in capital accruals, acquisitions (including any goodwill) and investments in affiliates.
[3]	The Midstream segment includes $220 million for the acquisition of the Ozark pipeline and an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system for the nine months ended September 30, 2017.
[4]	The nine months ended September 30, 2017 includes an investment of $500 million in MarEn Bakken related to the Bakken Pipeline system. The nine months ended September 30, 2016 includes an adjustment of $143 million to the fair value of equity method investments acquired in connection with the MarkWest Merger
[5]	We revised our operating segment presentation in the first quarter of 2017 in connection with the contribution of certain terminal, pipeline and storage assets to MPLX. The operating results for these assets, which were previously included in the Refining & Marketing segment, are now included in the Midstream segment. Comparable prior period information has been recast to reflect our revised presentation. The results for the pipeline and storage assets were recast effective January 1, 2015, and the results for the terminal assets were recast effective April 1, 2016. Prior to these dates, these assets were not considered businesses and, therefore, there are no financial results from which to recast segment results.
[6]	The Refining & Marketing and Speedway segments include inventory LCM benefits of $345 million and $25 million, respectively, for the nine months ended September 30, 2016
[7]	Corporate overhead expenses attributable to MPLX are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.
[8]	Corporate and other unallocated items consists primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets, except for corporate overhead expenses attributable to MPLX, which are included in the Midstream segment. Corporate overhead expenses are not allocated to the Refining & Marketing and Speedway segments.
[9]	Includes capitalized interest of $13 million and $15 million for the three months ended September 30, 2017 and 2016, respectively, and $39 million and $47 million for the nine months ended September 30, 2017 and 2016, respectively.
[10]	See Note 21 for further information on litigation matters.
[11]	2017 includes MPC’s share of gains related to the sale of assets remaining from the Sandpiper pipeline project. 2016 relates to impairments of goodwill and equity method investments.

Supplementary Statistics - Operating Statistics (Detail)
bbl / d in Thousands, gal in Millions, CFPD in Millions, $ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2017

USD ($)

Store

bbl / d

CFPD

$ / bbl

$ / gal

gal

Sep. 30, 2016

USD ($)

Store

bbl / d

CFPD

$ / bbl

$ / gal

gal

Sep. 30, 2017

USD ($)

Store

bbl / d

CFPD

$ / bbl

$ / gal

gal

Sep. 30, 2016

USD ($)

Store

bbl / d

CFPD

$ / bbl

$ / gal

gal

Operating Statistics [Line Items ]

^[1]

2,357

2,316

2,272

2,274

Refining & Marketing

Refining & Marketing refined product sales volume (thousands of barrels per day)

^[2]

2,357

2,307

2,263

2,265

Refining & Marketing gross margin (dollars per barrel) | $ / bbl

^[3],[4]

14.14

10.67

12.42

11.11

Crude oil capacity utilization percent

^[5]

102.00%

100.00%

96.00%

95.00%

Refinery throughputs (thousands of barrels per day)

^[6]

2,017

1,926

1,917

1,864

Sour crude oil throughput percent

57.00%

59.00%

61.00%

60.00%

WTI-priced crude oil throughput percent

23.00%

20.00%

Refined product yields (thousands of barrels per day)

^[6]

2,060

1,958

1,957

1,898

Inter-refinery transfers

80

89

74

80

Refinery direct operating costs (dollars per barrel):

Planned turnaround and major maintenance | $ / bbl

^[7]

1.20

1.62

1.69

1.72

Depreciation and amortization | $ / bbl

^[7]

1.34

1.42

1.44

1.46

Other manufacturing | $ / bbl

^[7],[8]

3.83

4.01

4.10

4.03

Total | $ / bbl

^[7]

6.37

7.05

7.23

7.21

Refining & Marketing | Crude oil refined

Refinery throughputs (thousands of barrels per day)

^[6]

1,845

1,791

1,741

1,708

Refining & Marketing | Other charge and blendstocks

Refinery throughputs (thousands of barrels per day)

^[6]

172

135

176

156

Refining & Marketing | Gasoline

Refined product yields (thousands of barrels per day)

^[6]

939

907

910

908

Refining & Marketing | Distillates

Refined product yields (thousands of barrels per day)

^[6]

673

647

627

616

Refining & Marketing | Propane

Refined product yields (thousands of barrels per day)

^[6]

38

35

Refining & Marketing | Feedstocks and special products

Refined product yields (thousands of barrels per day)

^[6]

298

253

285

245

Refining & Marketing | Heavy fuel oil

Refined product yields (thousands of barrels per day)

^[6]

45

43

36

Refining & Marketing | Asphalt

Refined product yields (thousands of barrels per day)

^[6]

67

70

64

58

Refining & Marketing | Gulf Coast:

Refinery throughputs (thousands of barrels per day)

^[9]

1,340

1,258

1,260

1,256

Sour crude oil throughput percent

69.00%

72.00%

75.00%

73.00%

WTI-priced crude oil throughput percent

14.00%

8.00%

10.00%

7.00%

Refined product yields (thousands of barrels per day)

^[9]

1,377

1,285

1,294

1,285

Refinery direct operating costs (dollars per barrel):

Planned turnaround and major maintenance | $ / bbl

^[7]

0.90

2.05

1.86

1.87

Depreciation and amortization | $ / bbl

^[7]

1.05

1.14

1.15

1.13

Other manufacturing | $ / bbl

^[7],[8]

3.52

3.70

3.81

3.62

Total | $ / bbl

^[7]

5.47

6.89

6.82

6.62

Refining & Marketing | Gulf Coast: | Crude oil refined

Refinery throughputs (thousands of barrels per day)

^[9]

1,123

1,073

1,041

1,057

Refining & Marketing | Gulf Coast: | Other charge and blendstocks

Refinery throughputs (thousands of barrels per day)

^[9]

217

185

219

199

Refining & Marketing | Gulf Coast: | Gasoline

Refined product yields (thousands of barrels per day)

^[9]

538

511

525

530

Refining & Marketing | Gulf Coast: | Distillates

Refined product yields (thousands of barrels per day)

^[9]

438

411

393

407

Refining & Marketing | Gulf Coast: | Propane

Refined product yields (thousands of barrels per day)

^[9]

25

27

25

26

Refining & Marketing | Gulf Coast: | Feedstocks and special products

Refined product yields (thousands of barrels per day)

^[9]

326

289

310

283

Refining & Marketing | Gulf Coast: | Heavy fuel oil

Refined product yields (thousands of barrels per day)

^[9]

31

30

24

Refining & Marketing | Gulf Coast: | Asphalt

Refined product yields (thousands of barrels per day)

^[9]

19

17

15

Refining & Marketing | Midwest:

Refinery throughputs (thousands of barrels per day)

^[9]

757

731

688

Sour crude oil throughput percent

38.00%

39.00%

41.00%

39.00%

WTI-priced crude oil throughput percent

38.00%

39.00%

34.00%

41.00%

Refined product yields (thousands of barrels per day)

^[9]

763

762

737

693

Refinery direct operating costs (dollars per barrel):

Planned turnaround and major maintenance | $ / bbl

^[7]

1.60

0.72

1.22

1.26

Depreciation and amortization | $ / bbl

^[7]

1.72

1.80

1.90

Other manufacturing | $ / bbl

^[7],[8]

3.96

4.04

4.19

4.29

Total | $ / bbl

^[7]

7.28

6.48

7.21

7.45

Refining & Marketing | Midwest: | Crude oil refined

Refinery throughputs (thousands of barrels per day)

^[9]

722

718

700

651

Refining & Marketing | Midwest: | Other charge and blendstocks

Refinery throughputs (thousands of barrels per day)

^[9]

35

39

31

37

Refining & Marketing | Midwest: | Gasoline

Refined product yields (thousands of barrels per day)

^[9]

401

396

385

378

Refining & Marketing | Midwest: | Distillates

Refined product yields (thousands of barrels per day)

^[9]

235

236

234

209

Refining & Marketing | Midwest: | Propane

Refined product yields (thousands of barrels per day)

^[9]

14

13

11

Refining & Marketing | Midwest: | Feedstocks and special products

Refined product yields (thousands of barrels per day)

^[9]

50

51

47

40

Refining & Marketing | Midwest: | Heavy fuel oil

Refined product yields (thousands of barrels per day)

^[9]

15

13

12

Refining & Marketing | Midwest: | Asphalt